Mercury and Air Toxics Standards for Power Plants Electronic Reporting Revisions, 20342-20378 [2020-07471]

Agencies

• ENVIRONMENTAL PROTECTION AGENCY

[Federal Register Volume 85, Number 70 (Friday, April 10, 2020)]
[Proposed Rules]
[Pages 20342-20378]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2020-07471]



[[Page 20341]]

Vol. 85

Friday,

No. 70

April 10, 2020

Part II





Environmental Protection Agency





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40 CFR Part 63





Mercury and Air Toxics Standards for Power Plants Electronic Reporting 
Revisions; Proposed Rule

Federal Register / Vol. 85, No. 70 / Friday, April 10, 2020 / 
Proposed Rules

[[Page 20342]]


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ENVIRONMENTAL PROTECTION AGENCY

40 CFR Part 63

[EPA-HQ-OAR-2018-0794; FRL-10007-27-OAR]
RIN 2060-AU70


Mercury and Air Toxics Standards for Power Plants Electronic 
Reporting Revisions

AGENCY: Environmental Protection Agency (EPA).

ACTION: Proposed rule.

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SUMMARY: The U.S Environmental Protection Agency (EPA) is proposing 
amendments to the electronic reporting requirements for the National 
Emission Standards for Hazardous Air Pollutants: Coal- and Oil-Fired 
Electric Utility Steam Generating Units (also known as the Mercury and 
Air Toxics Standards (MATS)). This proposed action would revise and 
streamline the electronic data reporting requirements of MATS and 
increase data transparency by requiring use of one electronic reporting 
system, instead of two separate systems, and provide enhanced access to 
MATS data. No new continuous monitoring requirements would be imposed 
by this proposed action; instead, this action would reduce reporting 
burden, increase MATS data flow and usage, make it easier for 
inspectors and auditors to assess compliance, and encourage wider use 
of continuous emissions monitoring systems (CEMS) for MATS compliance. 
In addition, this proposed action would extend the current deadline for 
alternative electronic data submission via portable document format 
(PDF) files through December 31, 2023.

DATES: 
    Comments. Comments must be received on or before May 11, 2020.
    Public hearing. If anyone contacts us requesting a public hearing 
on or before April 15, 2020, we will hold a hearing. Additional 
information about the hearing, if requested, will be posted at https://www.epa.gov/mats/regulatory-actions-final-mercury-and-air-toxics-standards-mats-power-plants. See SUPPLEMENTARY INFORMATION for 
information on requesting and registering for a public hearing.

ADDRESSES: You may send comments, identified by Docket ID No. EPA-HQ-
OAR-2018-0794, by any of the following methods:
     Federal eRulemaking Portal: https://www.regulations.gov/ 
(our preferred method). Follow the online instructions for submitting 
comments.
     Email: [email protected]. Include Docket ID No. EPA-
HQ-OAR-2018-0794 in the subject line of the message.
    Instructions: All submissions received must include the Docket ID 
No. for this rulemaking. Comments received may be posted without change 
to https://www.regulations.gov/, including any personal information 
provided. For detailed instructions on sending comments and additional 
information on the rulemaking process, see the SUPPLEMENTARY 
INFORMATION section of this document.
    Out of an abundance of caution for members of the public and our 
staff, the EPA Docket Center and Reading Room will be closed to public 
visitors beginning at the close of business on March 31, 2020 (4:30 
p.m.) to reduce the risk of transmitting COVID-19. Our Docket Center 
staff will continue to provide remote customer service via email, 
phone, and webform. We encourage the public to submit comments via 
https://www.regulations.gov/ or email, as there will be a delay in 
process mail and no hand deliveries will be accepted. For further 
information on EPA Docket Center services, please visit us online at 
https://www.epa.gov/dockets.

FOR FURTHER INFORMATION CONTACT: Mr. Barrett Parker, Sector Policies 
and Programs Division (D243-05), Office of Air Quality Planning and 
Standards, U.S. Environmental Protection Agency, Research Triangle 
Park, NC 27711; telephone number: (919) 541-5635; email address: 
[email protected]. For general information concerning MATS, 
contact Ms. Mary Johnson, Sector Policies and Programs Division (D243-
01), Office of Air Quality Planning and Standards, U.S. Environmental 
Protection Agency, Research Triangle Park, NC 27711; telephone number: 
(919) 541-5025. For questions concerning the Emissions Collection and 
Monitoring Plan System (ECMPS) Client Tool and its implementation, 
contact Mr. Christopher Worley, Clean Air Markets Division, Mail Code 
6204M, U.S. Environmental Protection Agency, 1200 Pennsylvania Ave. NW, 
Washington, DC 20460; telephone number: (202) 343-9531; email address: 
[email protected].

SUPPLEMENTARY INFORMATION: The information in this preamble is 
organized as follows:

Table of Contents

I. Public Participation
II. General Information
    A. Does this action apply to me?
    B. What action is the Agency taking?
    C. What is the Agency's authority for taking this action?
    D. What are the incremental costs and benefits of this action?
III. Background
IV. What is the scope of these proposed amendments?
V. What specific amendments to 40 CFR part 63, subpart UUUUU, are 
proposed by this action?
    A. Proposed Revisions to the Reporting Requirements of MATS
    B. Revisions to Appendix A
    C. Revisions to Appendix B
    D. Addition to Appendix C
    E. Addition to Appendix D
    F. Addition to Appendix E
VI. Proposed Revisions to Other Rule Text
VII. Statutory and Executive Order Reviews
    A. Executive Order 12866: Regulatory Planning and Review and 
Executive Order 13563: Improving Regulation and Regulatory Review
    B. Executive Order 13771: Reducing Regulations and Controlling 
Regulatory Costs
    C. Paperwork Reduction Act (PRA)
    D. Regulatory Flexibility Act (RFA)
    E. Unfunded Mandates Reform Act (UMRA)
    F. Executive Order 13132: Federalism
    G. Executive Order 13175: Consultation and Coordination With 
Indian Tribal Governments
    H. Executive Order 13045: Protection of Children From 
Environmental Health Risks and Safety Risks
    I. Executive Order 13211: Actions Concerning Regulations That 
Significantly Affect Energy Supply, Distribution, or Use
    J. National Technology Transfer and Advancement Act (NTTAA)
    K. Executive Order 12898: Federal Actions To Address 
Environmental Justice in Minority Populations and Low-Income 
Populations

I. Public Participation

    Public hearing. Please contact Ms. Adrian Gates at (919) 541-4860 
or by email at [email protected] to request a public hearing, to 
register to speak at the public hearing, or to inquire as to whether a 
public hearing will be held.
    Docket. The EPA has established a docket for this rulemaking under 
Docket ID No. EPA-HQ-OAR-2018-0794. All documents in the docket are 
listed in Regulations.gov. Although listed, some information is not 
publicly available, e.g., Confidential Business Information (CBI) or 
other information whose disclosure is restricted by statute. Certain 
other material, such as copyrighted material, is not placed on the 
internet. Publicly available docket materials are available 
electronically in Regulations.gov.
    The EPA is temporarily suspending its Docket Center and Reading 
Room for public visitors to reduce the risk of transmitting COVID-19. 
Written

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comments submitted by mail will be delayed and no hand deliveries will 
be accepted. Our Docket Center staff will continue to provide remote 
customer service via email, phone, and webform. We encourage the public 
to submit comments via https://www.regulations.gov/. For further 
information and updates on EPA Docket Center services, please visit us 
online at https://www.epa.gov/dockets.
    The EPA continues to carefully and continuously monitor information 
from the Centers for Disease Control and Prevention, local area health 
departments, and our Federal partners so we can respond rapidly as 
conditions change regarding COVID-19.
    Instructions. Direct your comments to Docket ID No. EPA-HQ-OAR-
2018-0794. The EPA's policy is that all comments received will be 
included in the public docket without change and may be made available 
online at https://www.regulations.gov/, including any personal 
information provided, unless the comment includes information claimed 
to be CBI or other information whose disclosure is restricted by 
statute. Do not submit information that you consider to be CBI or 
otherwise protected through https://www.regulations.gov/ or email. This 
type of information should be submitted by mail as discussed below.
    The EPA may publish any comment received to its public docket. 
Multimedia submissions (audio, video, etc.) must be accompanied by a 
written comment. The written comment is considered the official comment 
and should include discussion of all points you wish to make. The EPA 
will generally not consider comments or comment contents located 
outside of the primary submission (i.e., on the Web, cloud, or other 
file sharing system). For additional submission methods, the full EPA 
public comment policy, information about CBI or multimedia submissions, 
and general guidance on making effective comments, please visit https://www.epa.gov/dockets/commenting-epa-dockets.
    The https://www.regulations.gov/ website allows you to submit your 
comment anonymously, which means the EPA will not know your identity or 
contact information unless you provide it in the body of your comment. 
If you send an email comment directly to the EPA without going through 
https://www.regulations.gov/, your email address will be automatically 
captured and included as part of the comment that is placed in the 
public docket and made available on the internet. If you submit an 
electronic comment, the EPA recommends that you include your name and 
other contact information in the body of your comment and with any 
digital storage media you submit. If the EPA cannot read your comment 
due to technical difficulties and cannot contact you for clarification, 
the EPA may not be able to consider your comment. Electronic files 
should not include special characters or any form of encryption and be 
free of any defects or viruses. For additional information about the 
EPA's public docket, visit the EPA Docket Center homepage at https://www.epa.gov/dockets.
    Submitting CBI. Do not submit information containing CBI to the EPA 
through https://www.regulations.gov/ or email. Clearly mark the part or 
all of the information that you claim to be CBI. For CBI information on 
any digital storage media that you mail to the EPA, mark the outside of 
the digital storage media as CBI and then identify electronically 
within the digital storage media the specific information that is 
claimed as CBI. In addition to one complete version of the comments 
that includes information claimed as CBI, you must submit a copy of the 
comments that does not contain the information claimed as CBI directly 
to the public docket through the procedures outlined in Instructions 
above. If you submit any digital storage media that does not contain 
CBI, mark the outside of the digital storage media clearly that it does 
not contain CBI. Information not marked as CBI will be included in the 
public docket and the EPA's electronic public docket without prior 
notice. Information marked as CBI will not be disclosed except in 
accordance with procedures set forth in 40 Code of Federal Regulations 
(CFR) part 2. Send or deliver information identified as CBI only to the 
following address: OAQPS Document Control Officer (C404-02), OAQPS, 
U.S. Environmental Protection Agency, Research Triangle Park, North 
Carolina 27711, Attention Docket ID No. EPA-HQ-OAR-2018-0794. Note that 
written comments containing CBI and submitted by mail will be delayed 
and no hand deliveries will be accepted.

II. General Information

A. Does this action apply to me?

    Categories and entities potentially affected by this proposed 
action include:

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                                                         Examples of
             Category                NAICS code 1        potentially
                                                     regulated entities
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Industry..........................          221112  Fossil fuel-fired
                                                     electric utility
                                                     steam generating
                                                     units (EGUs).
Federal government................        2 221122  Fossil fuel-fired
                                                     EGUs owned by the
                                                     Federal government.
State/local/tribal government.....        2 221122  Fossil fuel-fired
                                                     EGUs owned by
                                                     municipalities.
                                            921150  Fossil fuel-fired
                                                     EGUs in Indian
                                                     country.
------------------------------------------------------------------------
\1\ North American Industry Classification System.
\2\ Federal, state, or local government-owned and operated
  establishments are classified according to the activity in which they
  are engaged.

    This table is not intended to be exhaustive, but rather provides a 
guide for readers regarding entities likely to be regulated by this 
action. This table lists the types of entities that EPA is now aware 
could potentially be regulated by this action. Other types of entities 
not listed in the table could also be regulated. To determine whether 
your entity is regulated by this proposed action, you should carefully 
examine the applicability criteria in 40 CFR 63.9981 of the rule. If 
you have questions regarding the applicability of this action to a 
particular entity, consult either the air permitting authority for the 
entity or your EPA Regional representative as listed in 40 CFR 63.13.

B. What action is the Agency taking?

    The EPA proposes this rule to streamline the electronic data 
reporting requirements of MATS; to increase data transparency by making 
more of the MATS data available in Extensible Markup Language (XML) 
format; and to amend the reporting and recordkeeping requirements 
associated with performance stack tests, particulate matter (PM) and 
hydrogen chloride (HCl) CEMS, and PM continuous parameter monitoring 
systems (CPMS).

C. What is the Agency's authority for taking this action?

    The Agency's authority for taking this action is found at 42 U.S.C. 
7401 et seq.

D. What are the incremental costs and benefits of this action?

    As discussed in section VII.C of this preamble, this action is 
expected to

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reduce overall annual source burden by 11,000 hours per year, which 
when monetized is $15,079,000.

III. Background

    These proposed amendments would revise the recordkeeping and 
reporting requirements of the MATS rule, in response to concerns raised 
by the regulated community. The MATS rule originally required affected 
EGU owners or operators to report MATS rule emissions and compliance 
information electronically using two data systems. See 40 CFR 63.10031 
(77 FR 9304, February 16, 2012). Paragraph (a) of 40 CFR 63.10031 
required EGU owners or operators that demonstrate compliance by 
continuously monitoring mercury (Hg) and/or HCl and/or hydrogen 
fluoride (HF) emissions to use the Emissions Collection and Monitoring 
Plan System (ECMPS) Client Tool to submit monitoring plan information, 
quality assurance test results, and hourly emissions data in accordance 
with appendices A and B to subpart UUUUU of 40 CFR part 63. Paragraph 
(f) of 40 CFR 63.10031 required performance stack test results, 
performance evaluations of Hg, HCl, HF, sulfur dioxide 
(SO2), and PM CEMS, 30-boiler operating day rolling average 
values for certain parameters, Notifications of Compliance Status, and 
semiannual compliance reports to be submitted to the EPA's WebFIRE 
database via the Compliance and Emissions Data Reporting Interface 
(CEDRI).
    Subsequent to the publication of the MATS rule, stakeholders 
suggested to the EPA that the MATS rule electronic reporting burden 
could be significantly reduced if all of the required information were 
reported to one data system instead of two. The stakeholders also 
suggested that using one data system would benefit the EPA and the 
public in their review of MATS rule data, because the information would 
be reported in a consistent format. In view of these considerations, 
the stakeholders urged the EPA to consider amending the MATS rule to 
require all of the data to be reported through the ECMPS, a familiar 
data system that most EGU owners or operators have been using since 
2009 to meet the electronic reporting requirements of the Acid Rain 
Program.
    After careful consideration of the stakeholders' recommendations, 
the EPA concluded that the increased transparency of the emissions data 
and the reduction in reporting burden that could be achieved through 
the use of a single data system are consistent with Agency priorities. 
As a result, late in 2014 the EPA decided to take the necessary steps 
to require all of the electronic reports required by the MATS rule to 
be submitted through the ECMPS Client Tool. Those steps would include 
revising the MATS rule, modifying the ECMPS Client Tool, creating a 
detailed set of reporting instructions, and beta testing the modified 
software. Recognizing that insufficient time was available to complete 
these tasks before the initial compliance date for the MATS rule (April 
16, 2015), the Agency embarked on a two-phased approach to complete 
them.
    The first phase was completed when the EPA published a final rule 
requiring EGU owners or operators to suspend temporarily (until April 
16, 2017) the use of the CEDRI interface as the means of submitting the 
reports described in 40 CFR 63.10031(f) introductory text and (f)(1), 
(2), and (4), and to use the ECMPS Client Tool to submit PDF versions 
of these reports on an interim basis (see 80 FR 15510, March 24, 2015). 
The specific reports required to be submitted as PDF files included: 
Performance stack test reports containing enough information to assess 
compliance and to demonstrate that the testing was done properly; 
relative accuracy test audit (RATA) reports for SO2, HCl, 
HF, and Hg CEMS; RATA reports for Hg sorbent trap monitoring systems; 
response correlation audit (RCA) and relative response audit (RRA) 
reports for PM CEMS; 30-boiler operating day rolling average reports 
for PM CEMS, PM CPMS, and approved hazardous air pollutants (HAP) 
metals CEMS; Notifications of Compliance Status; and semiannual 
compliance reports. Title 40 CFR 63.10031(f)(6) of the March 24, 2015, 
final rule required each PDF version of a submitted interim report to 
include information that identifies the facility (name and address), 
the EGU(s) to which the report applies, the applicable rule citations, 
and other information. The rule further specified that in the event 
that implementation of the single data system initiative was not 
completed by April 16, 2017, the electronic reporting of MATS data 
would revert to the original two systems approach on and after that 
date.
    In the preamble to the March 24, 2015, final rule, the EPA outlined 
the second phase of the single data system initiative, to be executed 
during the interim PDF reporting period. In phase two: (1) The Agency 
would publish a direct final rule, requiring MATS-affected sources to 
use the ECMPS Client Tool to submit all required reports; and (2) a 
detailed set of reporting instructions would be developed and ECMPS 
would be modified to receive and process the data.
    Considering the magnitude of the rule changes that would be 
required to execute phase two, coupled with the need to specify data 
elements to be reported electronically for PM CEMS, PM CPMS, and HCl 
CEMS, the Agency decided to provide stakeholders an opportunity to 
review and comment on the proposed changes. The EPA issued the proposed 
rule on September 29, 2016.\1\ The comment period for the 2016 proposal 
(or previous proposal) was scheduled to close on October 31, 2016, but 
it was subsequently extended until November 15, 2016, in response to 
requests from several stakeholders for an extension.
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    \1\ 81 FR 67062, September 29, 2016.
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    Commenters were generally supportive of the initiative to simplify 
and streamline the MATS reporting requirements and to use the ECMPS 
Client Tool as the single MATS rule reporting system. However, they 
expressed serious concerns about the proposal to extend the interim PDF 
reporting process from April 16, 2017, to December 31, 2017. Although 
they favored an extension of the PDF reporting, they were unanimous in 
asserting that the proposed end date of December 31, 2017, would not 
allow enough time to finalize the rule, develop the necessary XML 
reporting formats and reporting instructions, and reprogram the ECMPS 
Client Tool. In addition, two data acquisition and handling system 
vendors stated that more time would be needed for them to adapt to the 
proposed changes and to develop the reporting software for their 
customers. Some of the commenters recommended that the EPA should 
extend the interim PDF reporting process through calendar year 2019; 
others suggested that the process should be extended for 6 to 8 
calendar quarters after finalization of the rule.
    In view of these considerations, on April 6, 2017, the EPA 
published a final rule extending the interim PDF file reporting process 
through June 30, 2018 (82 FR 16736). Technical corrections to appendix 
A were also included in the rule package. The rule went into effect on 
April 6, 2017. As the Agency was unable to compete the e-reporting 
provisions, another extension to the interim PDF file reporting 
process--through June 30, 2020--was promulgated on July 2, 2018 (83 FR 
30879). This action proposes to further extend the interim PDF 
reporting process through December 31, 2023, and proposes the remaining 
needed amendments to the MATS rule on

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electronic reporting. Note that these proposed amendments were 
developed after consideration of the comments received on the September 
29, 2016, proposal.

IV. What is the scope of these proposed amendments?

    This proposed action would amend the reporting requirements in 40 
CFR 63.10031 of the MATS regulation, and, for consistency with those 
changes, would amend related text in 40 CFR part 63, subpart UUUUU; 
specifically, 40 CFR 63.10000, 63.10005, 63.10009, 63.10010, 63.10011, 
63.10020, 63.10021, 63.10030, 63.10032, 63.10042, and Tables 3, 8, and 
9. The recordkeeping and reporting sections of appendices A and B are 
also proposed to be amended \2\ and three new appendices are proposed 
to be added to the rule, i.e., appendices C, D, and E. Instead of using 
the electronic reporting tool (ERT) to submit some of the MATS data via 
CEDRI and submitting the remainder through the ECMPS Client Tool, as 
was required by the original MATS rule, this proposed action would 
allow EGU owners or operators to use the ECMPS Client Tool to report 
all of the required information in XML and PDF files.
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    \2\ In 2015, the EPA published a technology-neutral performance 
specification and associated quality assurance (QA) test procedures 
for HCl monitors (see Performance Specification 18 (PS 18) and 
Quality Assurance Procedure 6 (Procedure 6) in 80 FR 38628, July 7, 
2015). That rule added certification and QA test requirements for 
sources electing to monitor HCl according to PS 18 and Procedure 6. 
This proposed action would require the results of the appendix B 
certification and QA tests to be reported electronically for periods 
beginning on January 1, 2024.
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V. What specific amendments to 40 CFR part 63, subpart UUUUU, are 
proposed by this action?

    The proposed amendments to 40 CFR part 63, subpart UUUUU, are 
discussed in detail in the paragraphs below.

A. Proposed Revisions to the Reporting Requirements of MATS

    The reporting requirements of MATS are proposed to be amended as 
follows:
    (1) The ECMPS Client Tool would be used as the exclusive data 
system for MATS reporting, in lieu of using both ECMPS and the CEDRI.
    (2) The interim PDF reporting process described in 40 CFR 
63.10031(f) would be further extended through December 31, 2023, to 
allow sufficient time for software development, programming, and 
testing. Until then, compliance with the emissions and operating limits 
would continue to be assessed based on the various PDF report 
submittals described in 40 CFR 63.10031(f) and data from Hg, HCl, HF, 
and SO2 CEMS and sorbent trap monitoring systems, as 
reported through the ECMPS Client Tool. On and after January 1, 2024, 
compliance with the emissions and operating limits would be assessed 
based on: (1) Quarterly compliance reports; (2) hourly data from all 
continuous monitoring systems (CMS) (including PM CEMS and PM CPMS) in 
XML format; (3) detailed reference method information for stack tests 
and CMS performance evaluations in XML format and PDF files; (4) 
Notifications of Compliance Status (if any), in PDF files; and, (5) if 
applicable, supplementary data in PDF files for EGUs using paragraph 
(2) of the definition of ``startup'' in 40 CFR 63.10042. The ECMPS 
Client Tool would be used to submit all of these reports and 
notifications.
    (3) In order to properly close out the interim PDF reporting 
process, 40 CFR 63.10031(f)(6) would state that PDF submittals will 
still be accepted as necessary for the reports required under paragraph 
(f) introductory text, (f)(1), (2), or (4) if the deadlines for 
submitting those reports extend beyond December 31, 2023. As an 
example, the last semiannual compliance report under the interim PDF 
reporting process would cover the period from July 1, 2023, through 
December 31, 2023; the deadline for submitting this report would be 
January 30, 2024, and the report would be submitted using the interim 
PDF reporting process.
    (4) Revised paragraph (f)(2) of 40 CFR 63.10031 would expand the 
quarterly reporting of 30- or 90-boiler operating day rolling average 
emission rates to include units monitoring Hg, HCl, HF, and/or 
SO2 emissions, and units using emissions averaging. This 
change is consistent with 40 CFR 63.10031(f)(2) of the current rule, 
which requires quarterly reporting of 30-boiler operating day rolling 
averages for EGUs using PM CEMS, PM CPMS, and approved HAP metals CEMS. 
Therefore, starting with the first quarter of 2024, the 30- or 90-
boiler operating day rolling averages (or, if applicable, rolling 
weighted average emission rates (WAERs) if emissions averaging is used) 
would be reported quarterly in XML format for all parameters (including 
Hg, HF, HCl, and SO2). However, instead of providing these 
rolling averages in separate, stand-alone reports, they would be 
incorporated into the quarterly compliance reports required under 40 
CFR 63.10031(g) (see section IV.A.(9) of this preamble, below).
    (5) Revised paragraphs (a)(1), (2), and (5) of 40 CFR 63.10031 
would clarify the electronic reporting requirements for the Hg, HCl, 
HF, SO2, and auxiliary CMS. Specifically:
    (i) Paragraph (a)(1) would require the electronic reporting 
requirements of appendix A to be met if Hg CEMS or sorbent trap 
monitoring systems are used.
    (ii) Paragraph (a)(2) would require the electronic reporting 
requirements of appendix B to be met, with one important qualification, 
if HCl or HF monitoring systems are used. Until December 31, 2023, if 
Performance Specification (PS) 18 in part 60, appendix B, is used to 
certify an HCl monitor and Procedure 6 in part 60, appendix F, is used 
for on-going quality assurance (QA) of the monitor, EGU owners or 
operators would temporarily report only data that the existing 
programming of ECMPS is able to accommodate, i.e., hourly HCl emissions 
data and the results of daily calibration drift tests and RATAs; 
records would have to be kept of all of the other required 
certification and QA tests and supporting data. The reason for this 
temporary, limited reporting is that PS 18 and Procedure 6 were not 
published until July 7, 2015; therefore, it was not possible to specify 
recordkeeping and reporting requirements for them in the original 
version of appendix B. Now that PS 18 and Procedure 6 have been 
finalized, this rule would add the necessary recordkeeping and 
reporting requirements, and the interim reporting for HCl would be 
discontinued as of January 1, 2024 (for further discussion, see section 
IV.C of this preamble).
    (iii) Paragraph (a)(5) would clarify the electronic reporting 
requirements for the SO2 CEMS and the auxiliary monitoring 
systems under MATS. Sources currently reporting SO2 mass 
emissions under the Acid Rain Program or Cross-State Air Pollution Rule 
already meet these requirements, except for paragraphs (a)(5)(iii)(C) 
and (E), which would require, respectively, quarterly reporting of an 
hourly SO2 emission rate data stream in units of the 
applicable MATS standard (i.e., pounds per British thermal units (lb/
MMBtu) or pounds per megawatt hours (lb/MWh)) and certification 
statements from the responsible official. Separate certification 
statements would be required for the 40 CFR part 75 programs and MATS. 
(Note: For consistency with the changes described in items (i) through 
(iii), immediately above, 40 CFR 63.10031(f)(3) would be removed and 
reserved).
    (6) Paragraphs (b)(1) and (2) of 40 CFR 63.10031 would be amended 
to recognize that some EGUs may have received extensions of their 
compliance

[[Page 20346]]

date under 40 CFR 63.6(i)(4). References to postmark dates for 
submittal of semiannual compliance reports paragraphs would be removed 
from paragraphs (b)(2) and (4); these reports currently are, and would 
continue to be, submitted electronically through ECMPS as PDF files, 
until they are superseded by quarterly compliance reports, starting in 
the first quarter of 2024.
    (7) The provision in 40 CFR 63.10031(b)(5), which allowed affected 
EGU owners or operators to follow alternate submission schedules for 
semiannual compliance reports would be removed. The uniform submission 
schedule described in 40 CFR 63.10031(b)(1) through (4) would be 
required for all affected EGUs, so that compliance with this reporting 
requirement can easily be tracked.
    (8) Revised 40 CFR 63.10031(b)(5) would require EGU owners or 
operators to discontinue submission of semiannual compliance reports 
when the interim PDF reporting period ends. The final semi-annual 
compliance report would cover the period from July 1, 2023, through 
December 31, 2023.
    (9) EGU owners or operators would submit quarterly compliance 
reports in lieu of the semiannual compliance reports, starting with 
reports covering the first quarter of 2023 (see 40 CFR 63.10031(g)). 
The quarterly compliance reports would retain many features of the 
semiannual reports and consolidate them with other reports that were 
originally required to be submitted separately on different schedules. 
These compliance reports would be due within 60 days after the end of 
each calendar quarter, which would allow sufficient time to receive the 
results of stack tests (particularly PM, HCl, and HF tests) performed 
at or near the end of a calendar quarter. Each quarterly compliance 
report would include the applicable data elements listed in sections 2 
through 13 of appendix E.
    The owner or operator's MATS compliance strategy determines which 
of the data elements in sections 2-13 of appendix E would be included 
in the quarterly compliance reports. If continuous emission monitoring 
were used to demonstrate compliance on a 30- or 90-boiler operating day 
rolling average basis, the quarterly compliance reports would include 
all of the 30- or 90-day averages calculated during the quarter. If 
emissions averaging were used, EGU owners or operators would report all 
of the 30- or 90-group boiler operating day WAERs calculated during the 
quarter. If periodic stack testing for compliance were performed 
(including Hg Low-Emitting EGU (LEE) tests and PM tests to set 
operating limits for PM CPMS), the EGU owner or operator would report a 
summary of each test completed during the calendar quarter and indicate 
whether the test has a special purpose (i.e., if it were to be used to 
establish LEE status or for emissions averaging).
    The quarterly compliance reports would retain and incorporate the 
following features of the semiannual compliance reports: (1) Boiler 
tune-up dates; (2) monthly fuel usage data; (3) process and control 
equipment malfunction information; (4) reporting of deviations; and (5) 
emergency bypass information, for certain EGUs that qualify for and 
elect to use the LEE compliance option for Hg. However, for EGU owners 
or operators who elect to (or are required to) use CMS to demonstrate 
compliance, these quarterly reports, to some extent, would move away 
from traditional ``exception only'' reporting. Currently, reporting of 
the excess emissions and monitor downtime information described in 40 
CFR 63.10(e)(3)(v) and (vi) in PDF files has been required as part of 
the semiannual compliance reports. That information includes, among 
other things, identification of excess emissions periods, 
identification of periods when the monitoring system was inoperative or 
out of control, the reasons for the excess emission and monitor 
downtime periods, corrective actions or preventative measures taken, 
description of repairs or adjustments to inoperative or out-of-control 
CMS, the total amount of source operating time in the reporting period, 
and the excess emissions and monitor downtime, expressed as percentages 
of the source operating time. As explained above, rather than this 
traditional exception-only reporting, these proposed amendments would 
require all of the 30- (or 90-) boiler operating day rolling averages 
or WAERs for all parameters to be included in the quarterly compliance 
reports. In addition, the following elements of the excess emissions 
summary, with slight modifications, are proposed to be included in the 
quarterly compliance reports: (1) The total number of source operating 
hours in the quarter and (2) the total number of hours of monitoring 
system downtime for various causes (known and unknown).
    As previously noted, the requirement to report deviations would be 
retained in the quarterly compliance reports. Specifically, the 
revisions to 40 CFR 63.10031(d) would require the applicable data 
elements in section 13 of appendix E to be reported, which include the 
nature of the deviation (section 13.2), a description of the deviation 
(section 13.3), and any corrective actions taken (section 13.4). 
Section 13.3 further specifies the minimum amount of information that 
would be reported in the description of certain deviations (i.e., 
unmonitored bypass stack usage, emissions or operating limit 
exceedances, monitoring system outages, and missed or late performance 
stack tests).
    We believe that consolidating information in quarterly compliance 
reports, as described above, rather than requiring separate submittals 
of 30- (or 90-) boiler operating day rolling average reports, excess 
emissions reports, and semiannual compliance reports that come in 
separately at different times during the year, greatly simplifies 
reporting and will make it easier for inspectors and auditors to assess 
compliance with the standards. Also, quarterly, as opposed to 
semiannual, reporting is advantageous because it shortens significantly 
the interval between the time that deviation or exceedance reporting on 
a term longer than quarterly occurs. Draft reporting instructions for 
the quarterly compliance reports are provided in the rule docket and on 
the OAQPS and Clean Air Markets Division (CAMD) websites. In response 
to comments received, these instructions have been modified from a 
previous draft version.
    (10) A new paragraph, (c)(10), is being proposed to be added to 
Sec.  63.10031 and would require malfunction information to be included 
in the semiannual compliance reports. This is not a new requirement; it 
was previously found in paragraph (g). However, as explained above, 
revised paragraph (g) would require quarterly compliance reports to be 
submitted, starting in 2024. Therefore, to avoid losing the requirement 
to report malfunction information in the semiannual compliance reports, 
the former paragraph (g) would be renamed as paragraph (c)(10) and 
would be added to the list of information that must be included in the 
semiannual reports. The introductory text of paragraph (c) would also 
be amended, to recognize the addition of paragraph (c)(10).
    (11) For consistency with the reporting requirements for the other 
CMS, the Agency is not proposing a requirement for sources using PM 
CPMS to submit separate quarterly excess emission summary reports in 
addition to the quarterly compliance reports. After careful 
consideration of comments on a previous proposal, we are persuaded that 
sufficient information to assess compliance with the operating limits 
of a PM CPMS would be provided

[[Page 20347]]

by: (1) The hourly PM CPMS response data reported in appendix D; (2) 
the quarterly compliance reports, which specify the operating limit of 
the PM CPMS, require deviations from the operating limit and monitoring 
requirements to be reported, and include summarized results of the PM 
tests used to develop the operating limits; and (3) the applicable 
reference method data for the PM tests required to be reported under 
sections 17-30 of appendix E.
    We are proposing to amend Table 9 to 40 CFR part 63, subpart UUUUU, 
as follows to reflect the transition away from exception-only 
reporting. The applicability of the recordkeeping and reporting 
requirements for excess emission and monitor downtime summary reporting 
in 40 CFR 63.10(c)(7), 63.7(c)(8), and 63.10(e)(3) would end on 
December 31, 2023, with the phase-out of the semiannual compliance 
reports.
    (12) One commenter on the previous proposal brought to light some 
inconsistencies in the rule; regarding the way in which periods of 
monitor downtime should be regarded and reported, i.e., whether or not 
they are reportable deviations. The commenter pointed out that 40 CFR 
63.10020(d) exempts monitoring equipment malfunctions and out-of-
control periods from being reported as deviations, whereas 40 CFR 
63.10010(h)(6)(i), (i)(5)(i)(A) and (B), and (j)(4)(i)(A) and (B) 
appear to say the opposite, requiring these downtime incidents to be 
included in ``annual deviation reports.'' The EPA never intended to 
exempt these particular monitor outages from being reported as 
deviations; the Agency meant for the exemption to apply only to routine 
QA and maintenance activities.\3\ Therefore, 40 CFR 63.10020(d) would 
be clarified, and the statements in 40 CFR 63.10010(h)(6)(i), 
(i)(5)(i)(A) and (B), and (j)(4)(i)(A) and (B) more closely represent 
the Agency's position. But even there, the text is problematic, because 
deviations are currently required to be reported in the semiannual 
compliance reports (not in ``annual deviation reports'') and will 
continue to be reported in the quarterly compliance reports when the 
transition to quarterly reporting occurs. To address the 
inconsistencies in 40 CFR 63.10020(d) and 63.10010(h)(6)(i), 
(i)(5)(i)(A) and (B), and (j)(4)(i)(A) and (B), the proposed rule would 
amend these rule sections by clarifying that monitor outages due to 
monitoring equipment malfunctions and out-of-control periods are 
deviations, and, therefore, would be reported as such in the compliance 
reports.
---------------------------------------------------------------------------

    \3\ The following statement from the preamble of the original 
MATS rule makes this clear: ``Hours when a monitoring system is out 
of service would be counted as hours of monitor down-time and may be 
a deviation from the monitoring requirements of this rule unless the 
rule provides an exception for routine quality control and 
maintenance activities.'' (77 FR 9375, February 16, 2012).
---------------------------------------------------------------------------

    The same commenter further asserted that there are other incorrect 
statements in 40 CFR 63.10010(h)(6)(i), (i)(5)(i)(A), and (j)(4)(i)(A) 
and (B), regarding the reporting of quality assurance/quality control 
(QA/QC) activities for PM CPMS, PM CEMS, and HAP metals CEMS. These 
rule sections all require the QA/QC activities to be reported ``per the 
requirements of 40 CFR 63.10031(b).'' However, the reference to 40 CFR 
63.10031(b), which provides the schedule for submitting semiannual 
compliance reports, appears to be a typographical error. The commenter 
recommended replacing it with a more general reference to 40 CFR 
63.10031. The EPA agrees with the commenter that the reference to 40 
CFR 63.10010(b) is inappropriate; but the comment led to examination of 
inconsistencies between language in 40 CFR 63.10010(h)(6)(i), 
(i)(5)(i)(A), and (j)(4)(i)(A) and (B) and language in 40 CFR 
63.10010(h)(7), (i)(5)(ii), and (j)(4)(ii). The former sections require 
QA/QC activities for PM CPMS, PM CEMS, and HAP metals CEMS to be 
reported, while the latter sections state that the results of 
monitoring system performance audits must only be made available ``upon 
request.'' The Agency maintains reporting of QA test results is 
mandatory for all CMS. In view of this, the EPA proposes the following 
amendments. First, the reference to 40 CFR 63.10010(b) in the last 
sentence in paragraphs (h)(6)(i) and (j)(4)(i)(A) and (B) would be 
removed. Second, paragraphs (h)(7) and (j)(4)(ii) would be revised to 
require the monitoring system performance evaluations of PM CPMS and 
HAP metals CEMS to be reported. Third, a new paragraph, (k), would be 
added to 40 CFR 63.10031, and would require the QA/QC activities for PM 
CPMS and HAP metals CEMS to be reported quarterly in PDF files; these 
reports would be due within 60 days after the end of each calendar 
quarter, starting with a report for the first quarter of 2024 or, if 
the methodology is not in use by the source owner or operator in the 
first quarter of 2024, starting with the first calendar quarter in 
which the PM CPMS or HAP metals CEMS methodology is used. Reporting as 
PDF files is appropriate because there are no standardized QA test 
procedures for these CMS in the CFR; their QA test requirements are 
found only in source-specific MATS monitoring plans and will likely 
vary from source-to-source. Finally, 40 CFR 63.10010(i) would be 
revised in light of the addition of appendix C; paragraph (i) now 
simply cross-references the appropriate sections of appendix C, 
regarding the certification, operation, maintenance, on-going QA, 
recordkeeping, and reporting requirements for PM CEMS.
    (13) In all cases in which periodic stack tests (including Hg LEE 
tests and PM tests that are used to develop PM CPMS operating limits) 
are performed to demonstrate compliance, the proposal would retain the 
requirement for the EGU owner or operator to provide the applicable 
reference method data in appendix E (i.e., sections 17 et seq.) for 
each stack test that is performed to demonstrate compliance. Each of 
these submittals would be required to accompany the quarterly 
compliance report that covers the calendar quarter in which the test 
was completed. For PM tests that are used to develop PM CPMS operating 
limits, you would also be required to include the information in 40 CFR 
63.10023(b)(2)(vi) as part of the Test Comment data element found in 
section 17.25 of appendix E.
    (14) The applicable reference method data in sections 17 through 30 
of appendix E would also be provided in XML format, starting with tests 
completed on or after January 1, 2024, for each RATA of an Hg, 
SO2, HCl, or HF monitoring system, and for each RRA, RCA, or 
correlation test of a PM CEMS. The information in section 31 of 
appendix E would also be provided in a PDF file for each test. The 
appendix E information would be submitted concurrently with the 
summarized electronic test results submitted to ECMPS under appendix A, 
B, or C, or 40 CFR part 75 (for SO2 RATAs).
    (15) The ECMPS Client Tool would also be used to make the following 
submittals in PDF files:
    (i) A detailed report of the current, active PS 11 correlation 
test, if the EGU owner or operator is using a certified PM CEMS to 
demonstrate compliance. For correlation tests completed prior to [DATE 
60 DAYS AFTER DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL 
REGISTER], the report would be due no later than 60 days after that 
date. For correlation tests completed on or after [DATE 60 DAYS AFTER 
DATE OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], but 
prior to January 1, 2024, the report would be due within 60 days after 
the date on which the test is completed. (Note: For correlations 
completed on and after January 1, 2024,

[[Page 20348]]

in lieu of a PDF report, the test results would be submitted 
electronically according to section 7.2.4 of appendix C, together with 
the applicable reference method data required under sections 17 through 
31 of appendix E);
    (ii) Any initial Notification of Compliance Status issued on or 
after January 1, 2024; and
    (iii) The information specified in 40 CFR 63.10031(c)(5)(ii) and 
63.10020(e) for startup and shutdown incidents, if you are relying on 
paragraph (2) of the definition of ``startup'' in 40 CFR 63.10042. 
Starting with a report covering the first calendar quarter of 2024, 
this information would be submitted along with the quarterly compliance 
report. Note that 40 CFR 63.10031(c)(5)(iii) through (v), which require 
the semiannual compliance reports to include the hourly CEMS and 
operating parameter data recorded during startup and shutdown events 
have not been carried over to this PDF report because this information 
is duplicative of the hourly data reported electronically in the 
quarterly emissions reports. Startup and shutdown hours are flagged in 
the emissions reports and are identifiable for auditing purposes.
    (16) To accommodate the required PDF reports, the applicable data 
elements in 40 CFR 63.10031(f)(6)(i) through (xii) would be proposed to 
be entered into the ECMPS Client Tool at the time of submission of each 
PDF file. Note that the amendment to data element (xii) would replace 
the word ``conducted'' with the word ``completed.''
    (17) Although the ECMPS Client Tool would be used to submit the 
required reports and notifications described in revised 40 CFR 63.10031 
and Table 8, ECMPS would not evaluate any of the PDF submittals or any 
of the XML-formatted reference method data from sections 17 through 31 
of appendix E. Instead, these reports and notifications would be 
transmitted directly through the EPA's Central Data Exchange using 
CEDRI unaltered. ECMPS would, however, perform electronic checking of 
the hourly PM CEMS data and the summarized RATAs, PM CEMS correlation 
tests, RRAs, and RCAs that are submitted in XML format, in a manner 
that is consistent with the way that certification and QA test results 
are evaluated under the Acid Rain and Cross-State Air Pollution Rule 
programs. ECMPS would use the results of these evaluations to assess 
the quality-assured status of the Hg, HCl, HF, SO2, or PM 
emissions data. In addition, ECMPS would perform basic checks of the 
information in the quarterly compliance reports, e.g., checking for 
completeness and proper formatting, but would leave compliance 
assessment to those who review the reports. The EPA intends for all of 
these various data submissions to work together in a complementary 
fashion to enable meaningful compliance determinations. It is essential 
that any problems with the data identified by the reviewers are 
communicated to all involved and resolved appropriately. For example, 
if, for a particular Hg RATA, a review of the reference method data 
shows that the method was not done properly, the RATA would be 
invalidated. If, at the time of this discovery, the deadline for 
performing the RATA has passed and the allowable grace period has also 
expired, this would result in invalidation of hourly emissions data, 
from the expiration of the grace period until a valid RATA is performed 
and passed. Consequently, resubmission of quarterly emissions reports, 
recalculation of 30-day compliance averages, and resubmission of 
quarterly compliance reports may become necessary.

B. Revisions to Appendix A

    We are proposing to amend four sections of appendix A, i.e., 
sections 7.1.3.3, 7.1.4.3, 7.1.8.2 and 7.2.3.1, based on comments 
received. The requirement in sections 7.1.3.3, 7.1.4.3, and 7.1.8.2 to 
report Hg concentrations and emission rates to 3 significant figures 
would be revised so that Hg concentrations in micrograms per standard 
cubic meter ([mu]g/scm) and Hg emission rates in pounds per trillion 
British Thermal Units or pounds per gigawatt-hour (lb/TBtu or lb/GWh) 
would be reported with one leading non-zero digit and one decimal 
place, in scientific notation. Conventional rounding would be used, 
i.e., if the digit immediately following the first decimal place is 5 
or greater, the digit in the first decimal place would be rounded 
upward (increased by one); if the digit immediately following the first 
decimal place is 4 or less, the digit in the first decimal place would 
remain unchanged.
    The requirement in section 7.2.3.1 to submit monitoring plan 
information at least 21 days before the applicable compliance date in 
40 CFR 63.9984 would be revised. For new units or units that install Hg 
monitoring systems in order to switch from another MATS-compliant 
methodology to Hg monitoring, the monitoring plan information would be 
submitted at least 21 days prior to the date on which certification 
testing begins. However, for units implementing Hg monitoring with a 
previously-certified Hg monitoring system, the monitoring plan could be 
submitted prior to or concurrent with the first quarterly emissions 
report--provided that the monitoring plan would be in place when the 
first emissions report is submitted so that the ECMPS Client Tool would 
be able to evaluate the data.

C. Revisions to Appendix B

    For affected source owners or operators desiring to continuously 
monitor HCl emissions, the original version of appendix B required the 
monitoring system to be certified according to PS 15 in appendix B to 
40 CFR part 60. However, PS 15 applies only to Fourier Transform 
Infrared (FTIR) Spectroscopy monitoring systems; therefore, the use of 
other viable HCl monitoring technologies was excluded. In view of this, 
the EPA regarded the requirement to use PS 15 exclusively as a 
temporary measure, until a technology-neutral PS for HCl monitors could 
be developed and published. In section 3.1 of appendix B, the Agency 
stated its intention to publish such a PS in the near future together 
with appropriate on-going QA requirements and to amend appendix B to 
accommodate their use. This additional PS, (PS 18 in 40 CFR part 60, 
appendix B), and the on-going QA test requirements (Procedure 6 in 40 
CFR part 60, appendix F) were published on July 7, 2015 (80 FR 38628, 
July 7, 2015).
    Now that technology-neutral certification and QA test requirements 
for HCl monitors have been promulgated, EGU owners or operators may use 
any viable HCl monitoring technology that can meet the PS. However, in 
order for ECMPS to accommodate all of the tests required under PS 18 
and Procedure 6, additional time must be allotted for software 
development. In view of this, we are proposing to revise 40 CFR 
63.10031(a)(2), as previously noted, to require only information that 
is compatible with the existing programming of ECMPS to be reported 
electronically through December 31, 2023; this includes hourly HCl 
emissions data and the results of daily calibration drift tests and 
RATAs. In the interim, EGU owners or operators would be required to 
keep records of all of the other certification and QA tests, which 
would be reported starting in 2024.
    We are proposing to revise the title to section 2.3 of appendix B 
by deleting the reference to FTIR-only monitoring systems. In addition, 
the recordkeeping and reporting sections of appendix B (i.e., sections 
10 and 11) would be amended. Based on comments received, sections 
10.1.3.3 and 10.1.7.2, HCl and

[[Page 20349]]

HF concentrations ([micro]g/scm) and emission rates (lb/MMBtu or lb/
MWh) would be reported with one leading non-zero digit and one decimal 
place, in scientific notation, rather than reporting the concentrations 
and rates to 3 significant figures. Conventional rounding would be 
used, i.e., if the digit immediately following the first decimal place 
is 5 or greater, the digit in the first decimal place would be rounded 
upward (increased by one); if the digit immediately following the first 
decimal place is 4 or less, the digit in the first decimal place would 
remain unchanged. Sections 10 and 11 also specify the data elements 
that would be recorded and reported for each of the tests required by 
PS 18 and Procedure 6. The revisions would make a clear distinction 
between the tests required for FTIR monitors that are following PS 15 
and the test requirements of PS 18 and Procedure 6. Some of the tests 
in PS 18 and Procedure 6 are similar to tests for which ECMPS 
programming exists. For example, the ``measurement error test'' 
required for initial certification of the HCl monitor is structurally 
the same as a 40 CFR part 75 linearity check. Other tests have no 
counterpart in 40 CFR part 75 and would require special software 
development and reporting instructions. Note that electronic reporting 
of these tests through ECMPS would have been required if PS 18 and 
Procedure 6 had been in place when the original MATS rule was 
published. In view of this, for source owners or operators electing to 
use HCl CEMS, the amendments to section 11 of appendix B would 
introduce no unnecessary reporting burden. The results of certification 
and on-going QA tests would be reported electronically for all CEMS 
required under this rule in order for ECMPS to assess the quality-
assured status of the emissions data. The Agency also notes that not 
all of the tests described in section 11 of appendix B would be 
required for all HCl monitors. For example, some of the tests (i.e., 
beam intensity, temperature, and pressure verifications) are specific 
to Integrated Path--Continuous Emission Monitoring Systems (IP-CEMS), 
and Procedure 6 would offer a choice among three different types of 
audits (i.e., cylinder gas audits, relative accuracy audits, or dynamic 
spiking audits) for the required quarterly QA tests. In addition, based 
on comments received, the reporting requirements for the interference 
check (which is not necessarily performed on each individual analyzer) 
would be reduced.
    For each RATA of HCl CEMS that are completed on and after January 
1, 2024, the applicable reference method data in sections 17 through 31 
of appendix E would be submitted along with the electronic summary of 
results required under section 11 of appendix B. To the extent 
practicable, these data would be submitted prior to or concurrent with 
the relevant quarterly electronic emissions report. However, as 
previously noted, this may not always be possible, particularly when 
the RATA is done near the end of a calendar quarter. The EPA test 
Methods 26 and 26A, unlike instrumental test methods, require 
laboratory analyses of the collected samples and cannot provide test 
results while the test team is on-site. In view of this, section 11.4 
of appendix B would allow the test results to be submitted up to 60 
days after the test completion date. ``Provisional'' status may be 
claimed for the emissions data affected by the test, starting from the 
date and hour in which the test was completed, and continuing until the 
date and hour in which the test results are submitted. If the test is 
successful, the status of the data in that time period would change 
from provisional to quality-assured, and no further action is required. 
However, if the test is unsuccessful, the provisional data would be 
invalidated and resubmission of the affected emissions report(s) would 
be required.
    Because a technology-neutral PS for HCl CEMS was not available 
prior to April 16, 2015 (which was the compliance date for many of the 
existing EGUs), EGU owners or operators interested in monitoring HCl 
either had to use an FTIR system and follow PS 15 or implement another 
compliance option (e.g., quarterly emission testing) while awaiting 
publication of PS 18 and Procedure 6. In light of this, the EPA 
proposes to revise and restructure section 11.5.1 of appendix B to 
clarify when electronic reporting of hourly HCl emissions data begins. 
There are two possibilities. In the first case, the monitor is used for 
the initial compliance demonstration. This could either apply to a 
certified FTIR monitor following PS 15 or to a certified monitor 
following PS 18, if the owner or operator of the EGU received an 
extension of the compliance date. In this case, EGU owners or operators 
would begin reporting hourly HCl emissions through ECMPS with the first 
operating hour of the initial compliance demonstration. In the second 
case, another option, such as stack testing, is used for the initial 
compliance demonstration and continuous monitoring is implemented at a 
later time. In that case, EGU owners or operators would begin reporting 
hourly HCl emissions reporting through ECMPS with the first operating 
hour after successfully completing all required certification tests of 
the CEMS. In either case, the first quarterly emissions report 
submittal would be for the calendar quarter in which emissions 
reporting begins.
    The requirement in section 11.3.1 to submit monitoring plan 
information at least 21 days before the applicable compliance date in 
40 CFR 63.9984 would be revised. For new units or units that install 
HCl and/or HF monitoring systems in order to switch from another MATS-
compliant methodology to HCl and/or HF monitoring, the monitoring plan 
information would be submitted at least 21 days prior to the date on 
which certification testing begins. However, for units implementing HCl 
and/or HF monitoring with a previously-certified monitoring system, the 
monitoring plan could be submitted prior to or concurrent with the 
first quarterly emissions report.

D. Addition of Appendix C

    A new appendix, i.e., appendix C, would been added to subpart UUUUU 
of 40 CFR part 63. Appendix C sets forth the continuous monitoring and 
reporting requirements for filterable PM. Appendix C is structurally 
similar to appendices A and B, but there is one notable difference. 
Appendix C would include provisions for installation and certification 
of the PM CEMS, and for on-going QA of the data from the CEMS. The 
monitoring system would be certified according to PS 11 in 40 CFR part 
60, appendix B, and for the on-going QA tests, Procedure 2 to 40 CFR 
part 60, appendix F, would be required.
    After consideration of comments received, the EPA has concluded 
that all PM concentrations should be reported in units of measure that 
are consistent with the PM CEMS correlation. For example, if the PM 
CEMS measures in units of milligrams per actual cubic meter (mg/acm) 
and the concentrations used to derive the correlation curve are in 
those same units, then the hourly PM concentrations would be recorded 
and reported in mg/acm. Section 7.1.9.5 of appendix C would also 
require the reference method readings and the PM CEMS responses 
obtained in the RRAs and RCAs to be reported in the same units of 
measure as the PM CEMS correlation curve.
    Sections 7.1.3.3 and 7.1.7.2 would require PM concentrations and 
emission rates (lb/MMBtu or lb/MWh) to be reported with one leading 
non-zero digit and one decimal place, in scientific notation, rather 
than reporting the

[[Page 20350]]

concentrations and rates to three significant figures. Conventional 
rounding would be used, i.e., if the digit immediately following the 
first decimal place is 5 or greater, the digit in the first decimal 
place would be rounded upward (increased by one); if the digit 
immediately following the first decimal place is 4 or less, the digit 
in the first decimal place would remain unchanged.
    The proposed frequencies for the on-going QA tests and the rules 
for data validation are presented in Section 5 of appendix C. In 
response to numerous requests from commenters, the frequency and data 
validation rules for the RCAs and RRAs are similar, but not identical 
to, provisions of 40 CFR part 75. The frequency of these tests would 
follow the familiar calendar quarter and grace period reporting plan. 
An RRA would be required once every four calendar quarters and an RCA 
would be required once every 12 calendar quarters. A grace period would 
be provided (i.e., 720 operating hours or one calendar quarter, 
whichever comes first), to cover cases where circumstances beyond the 
control of the owner or operator prevent the required test from being 
completed on schedule. In addition, as explained in detail below, 
section 7.2.4 of appendix C would allow the use of provisional data for 
up to 60 days after completion of an RRA, RCA, or PM CEMS correlation 
test.
    The proposed procedures for calculating the PM emission rates in 
units of the emission standard are found in section 6. These 
calculation methods are basically the same as those used for Hg 
monitoring systems and for HCl and HF CEMS in appendices A and B. The 
proposed recordkeeping and reporting requirements are found in section 
7. Section 7.1 proposed that monitoring plan records and hourly records 
of operating parameters, PM concentration, diluent gas concentration, 
stack gas flow rate and moisture content, and PM emission rate would be 
kept. Sections 7.2.3 and 7.2.4, respectively, would require monitoring 
plan information and the results of certification, recertification, and 
QA tests to be reported electronically. For consistency with these 
revisions to appendices A and B, section 7.2.3.1 would specify that for 
new units or units installing PM CEMS in order to switch from another 
MATS-compliant methodology to PM monitoring, the electronic monitoring 
plan information would be submitted at least 21 days prior to the 
commencement of certification testing. However, for units with 
previously-certified PM CEMS that elect to implement PM monitoring, the 
monitoring plan information could be submitted prior to or concurrent 
with the first quarterly emissions report. Section 7.2.5 would require 
quarterly electronic emissions reports to be submitted within 30 days 
after the end of each calendar quarter. All electronic reports would be 
submitted using the ECMPS Client Tool. However, for EGUs that have 
begun using the PM CEMS compliance option prior to January 1, 2024, 
electronic reporting of monitoring plan information, certification and 
on-going QA test results, hourly PM emissions data, and the applicable 
reference method data in appendix E would not begin until January 1, 
2024, to allow time for software development and beta testing. Until 
then, records of the required information and tests would be kept. For 
EGUs that certify and begin using PM CEMS on or after January 1, 2024, 
reporting of hourly PM emissions data would begin with the first 
operating hour after successful completion of the initial PM CEMS 
correlation test.
    For PM CEMS correlations, RRAs, and RCAs that are completed on and 
after January 1, 2024, the applicable reference method data in sections 
17 through 31 of appendix E would be submitted along with the 
electronic test summary required under section 7.2.4 of appendix C. To 
the extent practicable, the electronic test results and the appendix E 
reference method data would be submitted prior to or concurrent with 
the relevant quarterly electronic emissions report. However, the EPA 
recognizes that this is not always possible, particularly when an RRA 
or RCA is done near the end of a calendar quarter. The EPA test Methods 
5 and 5D, unlike instrumental test methods, require laboratory analyses 
of the collected samples and generally cannot provide test results 
while the test team is on-site. In view of this, section 7.2.4 of 
appendix C would allow the test results to be submitted up to 60 days 
after the test completion date. ``Provisional'' status could be claimed 
for the emissions data affected by the test, starting from the date and 
hour in which the test was completed, and continuing until the date and 
hour in which the test results are submitted. If the test is 
successful, the status of the data in that time period would change 
from provisional to quality-assured, and no further action is required. 
However, if the test is unsuccessful, the provisional data would be 
invalidated, and resubmission of the affected emission report(s) would 
be required.

E. Addition of Appendix D

    We are proposing a second new appendix, i.e., appendix D, be added 
to subpart UUUUU of 40 CFR part 63. Appendix D would set forth the 
monitoring and reporting requirements for EGU owners or operators who 
elect to use a PM CPMS to demonstrate continuous compliance. 
Structurally, appendix D would be similar to appendices A, B, and C. 
However, the criteria for system design and performance, the procedures 
for determining operating limits, data reduction, and compliance 
assessment, and certain recordkeeping requirements are not detailed in 
the appendix; rather, the applicable sections of the MATS rule are 
cross-referenced (see sections 2.1 through 2.4, 3.1 introductory text, 
and section 3.1.1.1 of the appendix).
    Section 3.1.1.2 would require the ECMPS Client Tool to be used to 
create and maintain an electronic monitoring plan. The PM CPMS would be 
defined as a monitoring system with a unique system ID number. The 
monitoring plan would also include the current operating limit (with 
units of measure), the make, model, and serial number of the PM CPMS, 
the analytical principle of the monitoring system, and monitor span and 
range information.
    We are proposing to require operating parameter records for each 
hour of operation of the affected EGUs, including the date and hour, 
the EGU or stack operating time, and a flag to identify exempt startup 
and shutdown hours. Hourly average PM CPMS output values would be 
reported for each hour in which a valid value of the output parameter 
is obtained, in units of milliamps, PM concentration, or other units of 
measure, including the instrument's digital signal output equivalent. A 
special code would be required to indicate operating hours in which 
valid data are not obtained. The percent monitor data availability 
would also be calculated in the manner established for SO2, 
carbon dioxide (CO2), oxygen (O2), or moisture 
monitoring systems in 40 CFR 75.32.
    Sections 3.2.2 and 3.2.3, respectively, would require notifications 
(to be provided in accordance with section 63.10030) and electronic 
monitoring plan submittals at specified times. For units using the PM 
CPMS compliance option prior to January 1, 2024, the electronic 
monitoring plan information would be submitted prior to or concurrent 
with the first quarterly report. For units switching to the PM CPMS 
compliance option on or after January 1, 2024, the electronic 
monitoring plan would be submitted no

[[Page 20351]]

later than 21 days prior to the PM test that establishes the initial 
operating limit. Section 3.2.4 would require the electronic quarterly 
reports to be submitted within 30 days after the end of each calendar 
quarter. Reporting of hourly responses from the PM CPMS would begin 
either with the first operating hour of 2024 or the first operating 
hour after completion of the stack test that establishes the initial 
operating limit, whichever is later. Each quarterly report would 
include a compliance certification with a statement by a responsible 
official that to the best of his or her knowledge, the report is true, 
accurate, and complete.
    In addition to the electronic quarterly reports, we are proposing 
to require reporting of deviations from the operating limit in the 
quarterly compliance reports required under 40 CFR 63.10031(g). 
Further, section 3.2.5 of appendix D would require the results of each 
performance stack test for PM that is used to establish an operating 
limit to be reported electronically in the relevant quarterly 
compliance report. For PM tests completed on and after January 1, 2024, 
the applicable appendix E reference method data would also be submitted 
along with the relevant quarterly compliance report.

F. Addition of Appendix E

    We are proposing to add a third new appendix, i.e., appendix E, to 
subpart UUUUU of 40 CFR part 63. Sections 2 through 13 of appendix E 
list the data elements that would be reported in XML format in the 
quarterly compliance reports required under 40 CFR 63.10031(g), 
starting with reports covering the first quarter of 2024.
    The MATS compliance strategy (e.g., whether the EGU owner or 
operator elects to perform periodic stack testing, continuous 
monitoring, or to use emissions averaging) and the events that occur 
during each calendar quarter determine which data elements in sections 
2 through 13 would be included in the quarterly compliance reports. As 
noted in section V.A.(9), updated reporting instructions for these 
compliance reports are found in the rule docket and are posted on the 
CAMD and MATS websites.
    For reasons stated in the previous proposal's Response to Comments 
document (which is available in the rule docket \4\), we are proposing 
to retain the basic provisions of proposed sections 14 through 21 of 
appendix E, requiring details of the reference methods used for 
performance stack tests and continuous monitoring system performance 
evaluations to be reported in XML format. The rule would also retain 
the proposed requirement in section 22 of appendix E to provide 
reference method test information that is incompatible with electronic 
reporting as PDF files, although it has been renumbered as section 31 
and modified to include a cross-reference to 40 CFR 63.7(g), which 
describes the contents of a performance test report. The applicable 
reference method information in appendix E would be provided for each 
stack test; each RATA of a Hg, HCl, HF, or SO2 monitoring 
system; and each RRA, RCA, or correlation test of a PM CEMS that is 
completed on and after January 1, 2024.
---------------------------------------------------------------------------

    \4\ See EPA-HQ-OAR-2018-0794 at https://www.regulations.gov/.
---------------------------------------------------------------------------

    To address concerns raised by the commenters about portions of the 
2016 proposed rule \5\ (the previous proposal), specifically, the 
reporting requirements in sections 17 through 21 of proposed appendix 
E, the Agency proposes to revise and reformat the data element lists to 
correspond to the compliance options described in section 16 of 
appendix E. Explicitly, sections 17 through 30 would replace previously 
proposed sections 17 through 21. Commenters pointed out, and the Agency 
concurs, that some of the previously proposed data elements are either 
unnecessary, inapplicable to MATS, or duplicative of information in 
other MATS reports; these elements are proposed to be removed from the 
lists and include:
---------------------------------------------------------------------------

    \5\ As mentioned in footnote 1, see 81 FR 67062 from September 
29, 2016.
---------------------------------------------------------------------------

     Previously proposed 7.1.3.3.1 of appendix C to this 
subpart;
     Previously proposed 7.1.3.3.2 of appendix C to this 
subpart;
     Previously proposed 7.1.3.3.3 of appendix C to this 
subpart;
     Previously proposed 7.1.3.4 of appendix C to this subpart;
     Previously proposed 10.4 of appendix E to this subpart;
     Previously proposed 10.5.1 of appendix E to this subpart;
     Previously proposed 10.5.2 of appendix E to this subpart;
     Previously proposed 10.5.7 of appendix E to this subpart;
     Previously proposed 17.28 of appendix E to this subpart;
     Previously proposed 17.30 of appendix E to this subpart;
     Previously proposed 17.37 of appendix E to this subpart;
     Previously proposed 18.21 of appendix E to this subpart;
     Previously proposed 19.29 of appendix E to this subpart;
     Previously proposed 20.4 of appendix E to this subpart;
     Previously proposed 20.15 of appendix E to this subpart;
     Previously proposed 20.17 of appendix E to this subpart;
     Previously proposed 20.21 of appendix E to this subpart;
     Previously proposed 20.25 of appendix E to this subpart;
     Previously proposed 20.30 of appendix E to this subpart;
     Previously proposed 20.36 of appendix E to this subpart;
     Previously proposed 20.37 of appendix E to this subpart;
     Previously proposed 20.41 of appendix E to this subpart;
     Previously proposed 20.42 of appendix E to this subpart;
     Previously proposed 20.44 of appendix E to this subpart;
     Previously proposed 20.46 of appendix E to this subpart;
     Previously proposed 20.52 of appendix E to this subpart;
     Previously proposed 21.14 of appendix E to this subpart; 
and
     Previously proposed 21.28 of appendix E to this subpart.
    Reporting instructions for sections 17 through 30 have been 
developed. These proposed, draft example instructions are included in 
the rule docket and are posted on the MATS and CAMD websites.
    The reorganized data element lists and corresponding instructions 
clarify which data elements are proposed to be reported for each 
compliance option and explain how the data are to be reported. Several 
new data elements are proposed for the lists, to enable the ECMPS 
Client Tool to be used, to enhance the quality of the data, and to 
facilitate compliance. As mentioned in VI.C of this preamble, this 
proposed action is expected to reduce overall annual source burden. The 
Agency believes that the proposed addition of these data elements is 
offset by the proposed removal of others, the proposed change to a 
consistent submission frequency, and the proposed merger of separate 
electronic reporting systems into just one electronic reporting system 
such that overall annual source reporting burden is reduced by 11,000 
hours. The proposed new data elements to be reported are as follows:
     ``Part.'' The previous proposal would only have required 
the ``Subpart'' to be reported. To avoid any possible confusion with 
other EPA regulations, both the CFR part (63) and subpart (UUUUU) need 
to be included in the reports.
     ``APS Flags.'' For 3-level pre-test calibrations, system 
bias, and drift checks, instrumental EPA test Methods

[[Page 20352]]

3A and 6C require certain acceptance criteria to be met. For each of 
these tests, there is a main PS and an alternative specification. The 
main PS is expressed as a percentage of span, while the alternative 
specification is the absolute difference between a reference value and 
the measured value. In view of this, it is important to know which 
specification has been applied to ascertain whether the test was 
successful or not. Therefore, alternative performance specification 
(APS) flags are proposed to be added for the pre- and post-test 
calibrations, bias checks, and drift checks. An APS flag of ``0'' 
indicates that the reported test result is based on the main 
performance specification, whereas an APS flag of ``1'' means that the 
reported result is based on the alternative specification.
     ``Test Comment.'' This text field is proposed to be added 
to allow the affected sources to provide additional, pertinent 
information about a particular test.
     ``Run Begin Date'' and ``Run End Date.'' These two data 
elements are proposed to replace the previous proposed element ``Run 
Date'' to cover cases where a test run begins on one day and ends on 
another (e.g., if a run begins late at night and ends early the next 
morning).
     ``Converted Concentration and Units of Measure.'' These 
proposed data elements apply to correlation tests and performance 
audits (RRAs and RCAs) of PM CEMS. The reference method used for these 
tests is EPA test Method 5 (or, if applicable, 5D). The PM 
concentrations obtained from EPA test Method 5 or 5D are expressed in 
units of grams per dry standard cubic meter (g/dscm). However, 
consistent with section 8.6 of PS 11, appendix C of MATS proposes to 
require all PM concentrations to be reported in units of measure that 
are consistent with the PM CEMS correlation curve. Most PM CEMS measure 
concentration in units of milligrams per actual cubic meter (mg/acm); 
others may measure at a certain temperature (e.g., mg/acm at 160 
[deg]Celsius), and still others may measure on a dry basis. Therefore, 
in addition to reporting the EPA test Method 5 test results in units of 
g/dscm, the converted PM concentrations would be reported in units 
consistent with the PM CEMS correlation curve.
     ``Average Sampling Rate and Units of Measure.'' These 
proposed data elements are specific to EPA test Method 30B. That EPA 
test Method 30B requires a post-test leak check of each sampling train. 
The leakage rate must not exceed 4 percent of the average sampling 
rate. Therefore, to assess compliance with this specification, both the 
leakage rate and the average sampling rate would be reported. The 
previous proposed rule only required the leakage rate to be reported.
     ``Control Device Code.'' This proposed data element refers 
to the control device code or control technology National Emission 
Inventory (NEI) code associated with the EGU (or group of EGUs sharing 
a common stack). Providing this data element would help in EGU 
categorization and emission factor development.
     ``Corresponding Reference Method(s), if applicable.'' This 
proposed data element allows pollutant reference method run data to be 
associated with concurrent measurements of the stack gas flow rate 
using EPA test Method 2, and/or CO2 or O2 
concentration using EPA test Method 3A, and/or stack gas moisture 
content using EPA test Method 4. Reporting this data element is 
necessary to ensure test methods were conducted properly so that 
emission rates can be calculated.
     ``Corresponding Reference Method(s) Run Number, if 
applicable.'' This proposed data element provides the run number of 
concurrent reference method tests. The assigned run number of the EPA 
test Method 1 through 4 or EPA test Method 3A tests conducted at the 
same time as a reference method test needs to be reported in order to 
ensure the methods were conducted properly so that emission rates can 
be calculated.
     ``Pollutant Concentration Units of Measure.'' This 
proposed data element provides the appropriate units of measure code 
for the pollutant or analyte concentration, and reporting it is 
necessary for comparison to the standard.
     ``Pollutant Emission Rate.'' This proposed data element is 
the pollutant emission rate expressed in the units of the standard, and 
reporting it is necessary for comparison with the standard.
     ``Pollutant Emission Rate Units of Measure (in units of 
the standard).'' This proposed data element is the units of the 
standard specified in Table 1 or 2 of this subpart. Reporting it is 
necessary for comparison to the standard.
     ``Process Parameter Units of Measure.'' This proposed data 
element identifies the process rate parameter unit of measure: GWh/h, 
MWh/h, TBtu/h, or MMBTU/h, and reporting it is necessary to ensure 
accurate comparisons between runs and for emission factor development 
purposes.
     ``Total Pollutant Mass Trap A'' and ``Total Pollutant Mass 
Trap B.'' These proposed data elements refer to the total mercury mass 
measured by Train A and Train B, respectively, in the appropriate units 
of measure. Reporting these values is necessary for quality assurance 
purposes and for comparison with the standard.
     ``Method Detection Limit (MDL).'' This proposed data 
element refers to the minimum amount of analyte that can be detected 
and reported. Reporting it is necessary for calculation checks and for 
emissions factor development purposes.
     ``Percent Spike Recovery.'' This proposed data element 
refers to the spike recovery in percent, which is required to be 
reported by section 8.2.6.2 in EPA test Method 30B using Equation 30B-
1.
     ``F-Factor (Fc).'' This proposed data element 
expands the current F-factor choices to include the carbon F-Factor, 
which is based on the ratio of CO2 to heat content of fuel. 
Reporting it allows conversion from mass per volume to mass per heat 
input for those who choose to use emissions testing.
     ``Compliance Limit Basis (Heat Input or Electrical 
Output).'' This proposed data element identifies the denominator of the 
compliance units selected for an existing EGU by its owner or operator. 
Reporting this decision is necessary for comparison of results with the 
standard.
     ``Heat Input or Electrical Output Unit of Measure.'' This 
proposed data element specifies the denominator of the compliance unit 
that corresponds to the means of compliance selected for an existing 
EGU by its owner or operator. Reporting this unit is necessary for 
comparison of results with the standard and for emission factor 
development purposes.
     ``Pollutant Concentration.'' This proposed data element 
expands the already-existing ``Emissions Concentration'' data element 
to include pollutants. Reporting this data element is necessary for 
comparison of results with the standard and for emission factor 
development purposes.
     ``Stack Gas Flow Rate--dscfm.'' This proposed data element 
clarifies the already-existing ``Volumetric Flow Rate--scfm'' data 
element so that reporters will know to report their EGU's dry stack gas 
flow rate. Reporting this data element is necessary for calculation 
purposes. Several commenters \6\ on the September 29, 2016, proposed 
rule (i.e., the previous proposal) stated that those proposed revisions 
included a significant amount of duplicative reporting, which should be 
eliminated. In response to the

[[Page 20353]]

concerns expressed by the commenters, the Agency examined the XML data 
element lists for stack tests and CMS performance evaluations in order 
to identify duplicative reporting and eliminate it where possible. The 
following evaluations were made:
---------------------------------------------------------------------------

    \6\ Commenters 20612, 20597, and 20609 on Docket ID No. EPA-HQ-
OAR-2009-0234.
---------------------------------------------------------------------------

    First, the data elements in sections 2 through 13 of appendix E 
(for the quarterly compliance reports) were compared against the data 
elements in sections 17 through 30 of appendix E (corresponding to the 
detailed reference method data for stack tests and CMS performance 
evaluations). The two lists were found to have 20 data elements in 
common, but at least 9 of these elements (i.e., Source ID (Sampling 
Location), Test Number, Run Number, Run Begin Date, and a few others) 
are proposed to be included in both XML schemas to properly link the 
individual stack test summaries in the compliance report with the 
corresponding reference method data.
    Second, the data elements listed in the reporting sections of 
appendices A, B, and C of MATS, requiring the results of CMS 
performance evaluations (i.e., RATAs, RRAs, and RCAs) to be reported 
using the ECMPS Client Tool, were compared against the corresponding 
reference method data elements in sections 17 through 30 of appendix E. 
Only 12 data elements common to the appendix E and ECMPS Client Tool 
schemas were found. This is not surprising because appendices A, B, and 
C require only summarized results of CMS performance evaluations--
details of the Reference Method tests are not reported. Of the 12 data 
elements common to the appendix E and ECMPS lists, 10 of them are 
proposed to be included in both schemas to properly link the CMS test 
summaries with the corresponding reference method data. In view of 
these two evaluations, EPA concludes that most of the duplicative 
reporting found among the various data element lists is necessary to 
ensure that the results of stack tests and CMS performance evaluations 
summarized in the quarterly compliance reports and the QA test 
submittals to the ECMPS Client Tool can be matched with the 
corresponding Reference Method data. Further, the remainder of the 
duplicative reporting is minimal, rather than ``significant'' as 
asserted by the commenters. The Agency believes that it is best not to 
modify the data element lists to eliminate this small amount of 
duplicate reporting. Although the deadlines for submitting the 
quarterly compliance reports and the corresponding reference method 
data are the same (i.e., within 60 days after the end of the quarter), 
the two XML reports might not be submitted concurrently. So, if, for 
instance, the compliance report is submitted prior to the reference 
method data, and certain data elements are found only in the reference 
method report, a thorough assessment of compliance may not be possible 
until the reference method report is received. Similar considerations 
apply to the summarized CMS performance evaluations in the ECMPS Client 
Tool and the corresponding reference method data, if the two XML 
reports are not submitted concurrently.

VI. Proposed Revisions to Other Rule Text

    The revisions to 40 CFR 63.10031 necessitate changes to other 
sections of the rule to ensure that the rule is internally consistent. 
Based on comments received, revisions have also been made to clarify 
certain reporting requirements, to rectify inadvertent omissions, and 
to correct inconsistencies. The affected rule sections are as follows:
    (a) We are proposing to revise the introductory text of paragraphs 
(a)(2) and (b) of 40 CFR 63.10005. The amendment to paragraph (a)(2) 
would clarify that Hg compliance may either be determined on either a 
30- or 90-boiler operating day rolling average basis. For consistency 
with appendix E, revised paragraph (b) notes that when auxiliary stack 
gas flow rate or moisture data are needed to supplement a performance 
stack test conducted with an isokinetic method such as EPA test Method 
5 or EPA test Method 26A, separate EPA test Method 2 or EPA Method 4 
tests are not needed to satisfy the requirements of 40 CFR 63.10007 and 
Table 5. Data from the isokinetic method can be used to determine the 
stack gas flow rate and moisture content.
    (b) We are proposing to amend 40 CFR 63.10009 as follows. The 
second and third sentences in paragraph (a)(2) would be revised to 
clarify the types of data that may be used to determine WAERs. Data 
from Hg CEMS, sorbent trap monitoring systems, but not LEE tests, may 
be used for Hg emissions averaging. For other pollutants, both CEMS 
data and stack test data may be used. The last sentence of paragraph 
(a)(2) would be amended to clarify that if any EGU in an averaging 
group operates on any of the days in a 30- or 90-group boiler operating 
day compliance period (regardless of how many or how few), the 
emissions data from that EGU on those days must be included in the 
weighted average. Since averaging of Hg emissions is permitted on a 30-
group boiler operating day basis, Equations 2a and 2b in 40 CFR 
63.10009 apply to Hg as well as other pollutants. Therefore, the words 
``for pollutants other than Hg'' would be removed from the introductory 
text of paragraph (b)(2), and in the nomenclature of Equation 2a, the 
words ``or sorbent trap monitoring'' would be added after the words 
``unit i's CEMS'' in the definition of the term ``Heri.'' 
Finally, for completeness, Equations 3a and 3b would be amended by 
removing the terms that pertain to quarterly stack testing. Equations 
3a and 3b apply only to the 90-group boiler operating day Hg WAER limit 
for coal-fired units. Coal-fired EGUs do not have the option to use 
quarterly stack testing to demonstrate compliance; if a coal unit does 
not qualify as a LEE, Hg emissions must be continuously monitored.
    (c) As explained in section IV.A(11) above, we are proposing to 
revise paragraphs (h)(6) and (7), (i), and (j)(4)(i) and (ii) of 40 CFR 
63.10010 to resolve inconsistencies in the text.
    (d) We are proposing to revise 40 CFR 63.10011(e) to require 
Notifications of Compliance Status for initial compliance 
demonstrations to include the information specified in 40 CFR 
63.10030(e), and to be submitted in accordance with 40 CFR 
63.10031(f)(4) or (h), as applicable. This proposed change is necessary 
to cover initial Notifications of Compliance Status for both new and 
existing EGUs. The interim reporting process described in 40 CFR 
63.10031(f)(4) and the on-going reporting process in 40 CFR 63.10031(h) 
require these Notifications to be submitted as PDF files, through 
ECMPS.
    (e) We are proposing to revise 40 CFR 63.10011(g)(3), 40 CFR 
63.10021(i), and two sentences in Items 3 and 4 of Table 3 to be 
consistent with 40 CFR 63.10031(i) and Table 8. For EGU owners or 
operators relying on paragraph (2) of the definition of ``startup'' in 
40 CFR 63.10042, 40 CFR 63.10031(i) retains the requirement for the 
parametric data and other information in 40 CFR 63.10031(c)(5) to be 
included in the semiannual compliance reports, for startup and shutdown 
incidents that occur during the interim reporting period. However, in 
view of the proposed phase-out of the semiannual compliance reports, 
for startup and shutdown incidents that occur during each subsequent 
calendar quarter, starting with the first quarter of 2024, the 
supplementary information in 40 CFR 63.10031(c)(5)(ii) and 63.10020(e) 
would be required to be provided as a separate PDF submittal, along 
with the quarterly compliance report. As previously noted, the 
requirements in 40 CFR

[[Page 20354]]

63.10031(c)(5)(iii), (iv), and (v) to report hourly average CEMS and 
operating parameter values for startup and shutdown events are not 
proposed to be incorporated into this PDF report because they are 
duplicative of the hourly values reported under appendices A through D. 
Startup and shutdown hours are flagged in the quarterly emissions 
reports and can be identified for auditing purposes.
    (f) We are proposing revisions to paragraphs (e)(9), (f), and 
(h)(3) of 40 CFR 63.10021 as follows. Paragraph (e)(9) is unchanged 
from the previous proposal, except that the December 31, 2017, and 
January 1, 2018, transition dates are replaced with December 31, 2023, 
and January 1, 2024, respectively. We are proposing to remove 
references to the EPA's ERT and the CEDRI interface from paragraph (f) 
and replace it with a general statement requiring all applicable 
notifications and reports to be submitted through the ECMPS Client 
Tool. We are proposing to add three statements at the end of paragraph 
(f). The first statement, regarding a submission deadline that occurs 
on a weekend or Federal holiday, extends the deadline to the next 
business day. The second statement addresses a submission deadline that 
occurs when the ECMPS system is offline for maintenance; in that case, 
the deadline is extended until the first business day after the system 
outage. The third statement clarifies that using the ECMPS Client Tool 
to submit a required MATS report or notification satisfies the 
requirement in 40 CFR 63.13 of the General Provisions to submit that 
same report or notification (or the information contained in it) to the 
appropriate EPA Regional office or state agency whose delegation 
request has been approved. Finally, we are proposing to remove 
paragraph (h)(3) because it is redundant with paragraph (i) and, 
therefore, unnecessary.
    (g) We are proposing to remove 40 CFR 63.10030(e)(7)(i) for the 
following reasons. The requirement in the current rule for an initial 
Notification of Compliance Status to include summarized results of 
annual and triennial performance tests which have not been done yet is 
in an incorrect location. The requirement to submit these test 
summaries belongs in 40 CFR 63.10031, not 40 CFR 63.10030. Text similar 
to 40 CFR 63.10030(e)(7)(i) does, in fact, exist in 40 CFR 63.10031. 
Specifically, 40 CFR 63.10031(c)(7) requires the annual and triennial 
test results to be summarized in the semiannual compliance reports. 
Note, however, that when the semiannual compliance reports are phased 
out in 2024, the requirement to provide summarized results of these 
tests does not end; the test summaries must be included in the 
quarterly compliance reports under 40 CFR 63.10031(g).
    We are proposing to amend 40 CFR 63.10030(e)(7)(iii) to rectify an 
inadvertent oversight. In the 2016 Technical Corrections rule package, 
the EPA proposed a set of conditions that would allow an EGU owner or 
operator to submit a request for permission to switch from a heat 
input-based standard to an output-based standard. One of the proposed 
conditions, in paragraph (e)(7)(iii)(A)(3) required a demonstration of 
compliance with both emission limits, based on ``performance stack test 
results completed within 30 days prior to'' the request. A commenter 
objected to limiting this demonstration to ``stack test'' data and 
asked the EPA to allow any data collected up to 45 days prior to the 
request, including CEMS data, to be used. In the Response to Comments 
document, the EPA agreed with these commenters, but did not make the 
necessary changes to paragraph (e)(7)(iii)(A)(3) in the final rule. 
This rule corrects this oversight. In addition, we are proposing to add 
a note to paragraph (e)(7)(iii) to clarify that requests to switch from 
one standard to the other are made subsequent to, and are not part of, 
the initial Notification of Compliance Status.
    (h) We are proposing to amend 40 CFR 63.10032(a) to include 
references to the recordkeeping required under new appendices C (for PM 
CEMS), D (for PM CPMS), and E (for quarterly compliance reports and 
reference method test data). Also, in view of the move away from 
semiannual compliance reporting to quarterly reporting, we are 
proposing to replace the term ``semiannual compliance report'' with 
references to both semiannual and quarterly compliance reports in 
paragraph (a)(1).
    (i) We are proposing to remove the words ``or out of control 
period'' from 40 CFR 63.10042, from the definition of ``monitoring 
system malfunction or out of control period'' because that definition 
does not describe an out of control period. We are proposing to add a 
separate definition of ``out-of-control period,'' and that definition 
is similar with the definition provided in the Acid Rain Program 
definitions at 40 CFR 72.2.
    (j) We are proposing to revise Table 8 to subpart UUUUU of 40 CFR 
part 63 to be consistent with the amendments to 40 CFR 63.10031 and the 
proposed addition of appendices C, D, and E.
    (k) Finally, we are proposing to revise the recordkeeping and 
reporting requirements in Table 9 to 40 CFR part 63, subpart UUUUU, as 
follows. First, we are proposing changes to the requirement to provide 
the information in 40 CFR 63.10030(e)(1) through (8), i.e., it only 
applies to initial Notifications of Compliance Status; subsequent 
notifications are not required. Second, in keeping with the earlier 
discussion provided in section IV.A of this preamble, we are proposing 
to add a statement to clarify that the excess emissions recordkeeping 
and reporting requirements of 40 CFR 63.10(c)(7) and (8) and (e)(3)(v) 
and (vi) apply through December 31, 2023, when the semiannual 
compliance reports are phased out. On and after January 1, 2024, all 
relevant information will be provided in quarterly, as opposed to 
semiannual, reports.

VII. Statutory and Executive Order Reviews

    Additional information about these statutes and Executive orders 
can be found at https://www.epa.gov/laws-regulations/laws-and-executive-orders.

A. Executive Order 12866: Regulatory Planning and Review and Executive 
Order 13563: Improving Regulation and Regulatory Review

    This action is not a significant regulatory action and was, 
therefore, not submitted to the Office of Management and Budget (OMB) 
for review.

B. Executive Order 13771: Reducing Regulations and Controlling 
Regulatory Costs

    This action is considered an Executive Order 13771 deregulatory 
action. Details on the estimated cost savings of this proposed rule can 
be found in the EPA's analysis of the potential costs and benefits 
associated with this action.

C. Paperwork Reduction Act (PRA)

    The information collection activities in this proposed rule have 
been submitted for approval to OMB under the PRA. The Information 
Collection Request (ICR) document that the EPA prepared has been 
assigned EPA ICR number 2137.09. You can find a copy of the ICR in the 
docket for this proposed rule, and it is briefly summarized here.
    Respondents/affected entities: The respondents are owners or 
operators of fossil fuel-fired EGUs. The United States Standard 
Industrial Classification code for respondents affected by the rule is 
4911 (Electric Services). The corresponding NAICS code is 2211100 
(Electric Power Generation, Transmission, and Distribution).
    Respondent's obligation to respond: Mandatory per 42 U.S.C. 7414 et 
seq.

[[Page 20355]]

    Estimated number of respondents: 1,414.
    Frequency of response: Quarterly for compliance reports.
    Total estimated burden: Reduction of 11,000 hours (per year). 
Burden is defined at 5 CFR 1320.3(b).
    Total estimated cost: Savings of $15,079,000 (per year), includes 
$0 annualized capital or operation and maintenance costs.
    An agency may not conduct or sponsor, and a person is not required 
to respond to, a collection of information unless it displays a 
currently valid OMB control number. The OMB control numbers for the 
EPA's regulations in 40 CFR are listed in 40 CFR part 9.
    Submit your comments on the Agency's need for this information, the 
accuracy of the provided burden estimates, and any suggested methods 
for minimizing respondent burden to the EPA using the docket identified 
at the beginning of this rule. You may also send your ICR-related 
comments to OMB's Office of Information and Regulatory Affairs via 
email to [email protected], Attention: Desk Officer for the 
EPA. Since OMB is required to make a decision concerning the ICR 
between 30 and 60 days after receipt, OMB must receive comments no 
later than May 11, 2020. The EPA will respond to any ICR-related 
comments in the final rule.

D. Regulatory Flexibility Act (RFA)

    I certify that this action will not have a significant economic 
impact on a substantial number of small entities under the RFA. In 
making this determination, the impact of concern is any significant 
adverse economic impact on small entities. An agency may certify that a 
rule will not have a significant economic impact on a substantial 
number of small entities if the rule relieves regulatory burden, has no 
net burden, or otherwise has a positive economic effect on the small 
entities subject to the rule. For purposes of assessing the impacts of 
this rule on small entities, the EPA considered small entities to be 
defined as: (1) A small business that is an electric utility producing 
4 billion kilowatt-hours or less as defined by NAICS codes 221122 
(fossil fuel-fired electric utility steam generating units) and 921150 
(fossil fuel-fired electric utility steam generating units in Indian 
country); (2) a small governmental jurisdiction that is a government of 
a city, county, town, school district, or special district with a 
population of less than 50,000; and (3) a small organization that is 
any not-for-profit enterprise which is independently owned and operated 
and is not dominant in its field. As required by the RFA, the EPA 
proposed using this alternative definition in the Federal Register of 
May 3, 2011, 76 FR 25083, sought public comment, consulted with the 
Small Business Administration and finalized the alternative definition 
in the Federal Register of February 16, 2012, 77 FR 9433. As stated in 
that document, the alternative definition would apply to this 
regulation. This action reduces annual burden on small and large 
entities. We have, therefore, concluded that this action will relieve 
regulatory burden for all directly regulated small entities.

E. Unfunded Mandates Reform Act (UMRA)

    This action does not contain an unfunded mandate of $100 million or 
more as described in UMRA, 2 U.S.C. 1531-1538, and does not 
significantly or uniquely affect small governments.
    As described earlier, this action reduces annual burden on 
governments already subject to MATS; as a result, we have determined 
that this action will not result in any ``significant'' adverse 
economic impact for small governments.

F. Executive Order 13132: Federalism

    This action does not have federalism implications. It will not have 
substantial direct effects on the states, on the relationship between 
the National Government and the states, or on the distribution of power 
and responsibilities among the various levels of government.

G. Executive Order 13175: Consultation and Coordination With Indian 
Tribal Governments

    This action does not have tribal implications as specified in 
Executive Order 13175. As described earlier, this action has no 
substantial direct effect on Indian tribes already subject to MATS, 
since this action reduces their annual burden. Thus, Executive Order 
13175 does not apply to this action.

H. Executive Order 13045: Protection of Children From Environmental 
Health Risks and Safety Risks

    The EPA interprets Executive Order 13045 as applying only to those 
regulatory actions that concern environmental health or safety risks 
that the EPA has reason to believe may disproportionately affect 
children, per the definition of ``covered regulatory action'' in 
section 2-202 of the Executive order. This action is not subject to 
Executive Order 13045 because it does not concern an environmental 
health risk or safety risk.

I. Executive Order 13211: Actions Concerning Regulations That 
Significantly Affect Energy Supply, Distribution or Use

    This action is not subject to Executive Order 13211, because it is 
not a significant regulatory action under Executive Order 12866.

J. National Technology Transfer and Advancement Act (NTTAA)

    This rulemaking does not involve technical standards.

K. Executive Order 12898: Federal Actions To Address Environmental 
Justice in Minority Populations and Low-Income Populations

    The EPA believes that this proposed action is not subject to 
Executive Order 12898 (59 FR 7629, February 16, 1994) because it would 
not establish an environmental health or safety standard. This proposed 
regulatory action revises the way in which information is reported to 
the Agency, increasing submission frequency and making adaptions so 
that just one reporting system can be used, but reducing overall 
burden; this regulatory action does not have any impact on human health 
or the environment.

List of Subjects in 40 CFR Part 63

    Environmental protection, Administrative practice and procedure, 
Air pollution control, Hazardous substances, Intergovernmental 
relations, Reporting and recordkeeping requirements.

Andrew Wheeler,
Administrator.

    For the reasons set forth in the preamble, EPA proposes to amend 40 
CFR part 63 as follows:

PART 63--NATIONAL EMISSION STANDARDS FOR HAZARDOUS AIR POLLUTANTS 
FOR SOURCE CATEGORIES

0
1. The authority citation for part 63 continues to read as follows:

    Authority:  42 U.S.C. 7401 et seq.

Subpart UUUUU--National Emission Standards for Hazardous Air 
Pollutants: Coal- and Oil-Fired Electric Utility Steam Generating 
Units


Sec.  63.10000  [Amended]

0
2. In Sec.  63.10000, paragraph (d)(5)(vi) is amended by adding the 
words ``, where appropriate,'' immediately after the words ``CMS that 
is out of control consistent with Sec.  63.8(c)(7)(i)''.
0
3. Section 63.10005 is amended by:

[[Page 20356]]

0
a. Revising the first sentence in paragraph (a)(2) introductory text; 
and
0
b. Revising paragraph (b) introductory text.
    The revisions read as follows:


Sec.  63.10005  What are my initial compliance requirements and by what 
date must I conduct them?

    (a) * * *
    (2) To demonstrate initial compliance using either a CMS that 
measures HAP concentrations directly (i.e., an Hg, HCl, or HF CEMS, or 
a sorbent trap monitoring system) or an SO2 or PM CEMS, the 
initial performance test shall consist of 30- or, if applicable for Hg, 
90-boiler operating days. * * *
* * * * *
    (b) Performance testing requirements. If you choose to use 
performance testing to demonstrate initial compliance with the 
applicable emissions limits in Tables 1 and 2 to this subpart for your 
EGUs, you must conduct the tests according to Sec.  63.10007 and Table 
5 to this subpart. Notwithstanding the requirements in this subpart, 
when Table 5 specifies the use of isokinetic EPA test Method 5, 5D, 
26A, or 29 in appendices A-3 and A-8 to part 60 of this chapter for a 
stack test, if concurrent measurement of the stack gas flow rate or 
moisture content is needed to convert the pollutant concentrations to 
units of the standard, separate determination of these parameters using 
EPA test Method 2 or EPA test Method 4 in appendices A-1 and A-3 to 
part 60 of this chapter is not necessary. Instead, the stack gas flow 
rate and moisture content can be determined from data that are 
collected during the EPA test Method 5, 5D, 6, 26A, or 29 test (e.g., 
pitot tube (delta P) readings, moisture collected in the impingers, 
etc.). For the purposes of the initial compliance demonstration, you 
may use test data and results from a performance test conducted prior 
to the date on which compliance is required as specified in Sec.  
63.9984, provided that the following conditions are fully met:
* * * * *
0
4. Section 63.10009 is amended by:
0
 a. Revising in paragraph (a)(2) the second, third, and last sentences;
0
 b. In paragraph (b)(2):
0
i. In the introductory text, removing the words ``for pollutants other 
than Hg''; and
0
 ii. Adding in the definition for ``Heri'' the words ``or 
sorbent trap monitoring system'' after the words ``unit i's CEMS''; and
0
c. Revising ``Equation 3a'' and ``Equation 3b'' in paragraph (b)(3).
    The revisions read as follows:


Sec.  63.10009   May I use emissions averaging to comply with this 
subpart?

    (a) * * *
    (2) * * * Note that except for the alternate Hg emissions limit 
from EGUs in the ``unit designed for coal >= 8,300 Btu/lb'' 
subcategory, the averaging time for emissions averaging for pollutants 
is 30-group boiler operating days (rolling daily) using data from CEMS 
and sorbent trap monitoring (for Hg), or a combination of data from 
CEMS and emissions testing (for other pollutants). The averaging time 
for emissions averaging for the alternate Hg limit (equal to or less 
than 1.0 lb/TBtu or 1.1E-2 lb/GWh) from EGUs in the ``unit designed for 
coal >= 8,300 Btu/lb'' subcategory is 90-group boiler operating days 
(rolling daily) using data from CEMS, sorbent trap monitoring, or a 
combination of data from CEMS and sorbent trap monitoring. * * * You 
must calculate the weighted average emissions rate for the group in 
accordance with the procedures in this paragraph (a)(2) using the data 
from all units in the group including any that operate fewer than 30 
(or 90) of the preceding 30 (or 90) group boiler operating days.
* * * * *
    (b) * * *
    (3) * * *
    [GRAPHIC] [TIFF OMITTED] TP10AP20.001
    
Where:

Heri = Hourly emission rate from unit i's Hg CEMS or Hg 
sorbent trap monitoring system for the preceding 90-group boiler 
operating days;
Rmi = Hourly heat input or gross output from unit i for 
the preceding 90-group boiler operating days;
p = Number of EGUs in the emissions averaging group; and
n = Number of hours that hourly rates are collected over the 90-
group boiler operating days.
[GRAPHIC] [TIFF OMITTED] TP10AP20.002

Where:

Heri = Hourly emission rate from unit i's Hg CEMS or Hg 
sorbent trap monitoring system for the preceding 90-group boiler 
operating days;
Smi = Steam generation in units of pounds from unit i 
that uses Hg CEMS or Hg sorbent trap monitoring for the preceding 
90-group boiler operating days;
Cfmi = Conversion factor, calculated from the most recent 
compliance test results, in units of heat input per pound of steam 
generated or gross output per pound of steam generated, from unit i 
that uses Hg CEMS or sorbent trap monitoring from the preceding 90-
group boiler operating days;
p = Number of EGUs in the emissions averaging group; and
n = Number of hours that hourly rates are collected over the 90-
group boiler operating days.
* * * * *
0
5. Section 63.10010 is amended by revising paragraphs (h)(6) and (7), 
(i), and (j)(4) to read as follows:

[[Page 20357]]

Sec.  63.10010  What are my monitoring, installation, operation, and 
maintenance requirements?

* * * * *
    (h) * * *
    (6) You must use all the data collected during all boiler operating 
hours in assessing the compliance with your operating limit except:
    (i) Any data recorded during periods of monitoring system 
malfunctions or repairs associated with monitoring system malfunctions. 
You must report any monitoring system malfunctions as deviations in 
your compliance reports under Sec.  63.10031(c) or (g) (as applicable);
    (ii) Any data recorded during periods when the monitoring system is 
out-of-control (as specified in your site-specific monitoring plan), 
repairs associated with periods when the monitoring system is out of 
control, or required monitoring system quality assurance or quality 
control activities conducted during out-of-control periods. You must 
report any such periods as deviations in your compliance reports under 
Sec.  63.10031(c) or (g) (as applicable);
    (iii) Any data recorded during required monitoring system quality 
assurance or quality control activities that temporarily interrupt the 
measurement of output data from the PM CPMS; and
    (iv) Any data recorded during periods of startup or shutdown.
    (7) You must record and report the results of PM CPMS system 
performance audits, in accordance with Sec.  63.10031(k). You must also 
record and make available upon request the dates and duration of 
periods from when the PM CPMS is out of control until completion of the 
corrective actions necessary to return the PM CPMS to operation 
consistent with your site-specific monitoring plan.
    (i) If you choose to comply with the PM filterable emissions limit 
in lieu of metal HAP limits, you may choose to install, certify, 
operate, and maintain a PM CEMS and record and report the output of the 
PM CEMS as specified in paragraphs (i)(1) through (8) of this section. 
Compliance with the applicable PM emissions limit in Table 1 or 2 to 
this subpart is determined on a 30-boiler operating day rolling average 
basis.
    (1) You must install and certify your PM CEMS according to section 
4 of appendix C to this subpart.
    (2) You must operate, maintain, and quality-assure the data from 
your PM CEMS according to section 5 of appendix C to this subpart.
    (3) You must reduce the data from your PM CEMS to hourly averages 
in accordance with section 6.1 of appendix C to this subpart.
    (4) You must collect data using the PM CEMS at all times the 
process unit is operating except for periods of monitoring system 
malfunctions, out-of-control periods, repairs associated with 
monitoring system malfunctions or out-of-control periods, and required 
monitoring system quality assurance, quality control, or maintenance 
activities.
    (5) You must use all the data collected during all boiler operating 
hours in assessing the compliance with your emissions limit except:
    (i) Any data recorded during periods of monitoring system 
malfunctions and repairs associated with monitoring system 
malfunctions. You must report any monitoring system malfunctions as 
deviations in your compliance reports under Sec.  63.10031(c) or (g) 
(as applicable);
    (ii) Any data recorded during periods when the monitoring system is 
out-of-control (as specified in appendix C to this subpart), repairs 
associated with periods when the monitoring system is out of control, 
or required monitoring system quality assurance or quality control 
activities conducted during out-of-control periods. You must report any 
such periods as deviations in your compliance reports under Sec.  
63.10031(c) or (g) (as applicable);
    (iii) Any data recorded during required monitoring system quality 
assurance, quality control, or maintenance activities that temporarily 
interrupt the measurement of emissions (e.g., calibrations, certain 
audits, routine probe maintenance); and
    (iv) Any data recorded during periods of startup or shutdown.
    (6) You must keep records and report data from your PM CEMS in 
accordance with section 7 of appendix C to this subpart.
    (7) You must record and make available upon request the dates and 
duration of periods when the PM CEMS is out-of-control to completion of 
the corrective actions necessary to return the PM CEMS to operation 
consistent with your site-specific monitoring plan.
    (8) You must calculate each 30-boiler operating day rolling average 
PM emission rate in units of the applicable emissions limit in Table 1 
or 2 to this subpart, in accordance with section 6.2.4 of appendix C to 
this subpart.
    (j) * * *
    (4) You must collect data using the HAP metals CEMS at all times 
the process unit is operating and at the intervals specified in 
paragraph (a) of this section, except for periods of monitoring system 
malfunctions, out-of-control periods, repairs associated with 
monitoring system malfunctions or out-of-control periods, and required 
monitoring system quality assurance, quality control, or maintenance 
activities.
    (i) You must use all the data collected during all boiler operating 
hours in assessing the compliance with your emission limit except:
    (A) Any data collected during periods of monitoring system 
malfunctions and repairs associated with monitoring system 
malfunctions. You must report any monitoring system malfunctions as 
deviations in your compliance reports under Sec.  63.10031(c) or (g) 
(as applicable);
    (B) Any data collected during periods when the monitoring system is 
out of control as specified in your site-specific monitoring plan, 
repairs associated with periods when the monitoring system is out of 
control, or required monitoring system quality assurance or quality 
control activities conducted during out-of-control periods. You must 
report any out of control periods as deviations in your compliance 
reports under Sec.  63.10031(c) or (g) (as applicable);
    (C) Any data recorded during required monitoring system quality 
assurance or quality control activities that temporarily interrupt the 
measurement of emissions (e.g., calibrations, certain audits, routine 
probe maintenance); and
    (D) Any data recorded during periods of startup or shutdown.
    (ii) You must record and report the results of HAP metals CEMS 
system performance audits, in accordance with Sec.  63.10031(k) You 
must also record and make available upon request the dates and duration 
of periods when the HAP metals CEMS is out of control to completion of 
the corrective actions necessary to return the HAP metals CEMS to 
operation consistent with your site-specific performance evaluation and 
quality control program plan.
* * * * *
0
 6. Section 63.10011 is amended by revising paragraphs (e) and (g)(3) 
to read as follows:


Sec.  63.10011  How do I demonstrate initial compliance with the 
emissions limits and work practice standards?

* * * * *
    (e) You must submit a Notification of Compliance Status in 
accordance with Sec.  63.10031(f)(4) or (h), as applicable, containing 
the results of the initial compliance demonstration, as specified in 
Sec.  63.10030(e).
* * * * *
    (g) * * *
    (3) You must report the emissions data recorded during startup and

[[Page 20358]]

shutdown. If you are relying on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042, then for startup and shutdown incidents 
that occur on or prior to December 31, 2023, you must also report the 
applicable supplementary information in Sec.  63.10031(c)(5) in the 
semiannual compliance report. For startup and shutdown incidents that 
occur on or after January 1, 2024, you must provide the applicable 
information in Sec. Sec.  63.10031(c)(5)(ii) and 63.10020(e) quarterly, 
in PDF files, in accordance with Sec.  63.10031(i).
* * * * *


Sec.  63.10020  [Amended]

0
 7. In Sec.  63.10020, paragraph (b) is amended by removing the words 
``(see Sec.  63.8(c)(7) of this part)''.
0
 8. Section 63.10021 is amended by:
0
a. Revising paragraphs (e)(9) and (f);
0
b. Removing and reserving paragraph (h)(3); and
0
c. Revising paragraph (i).
    The revisions read as follows:


Sec.  63.10021  How do I demonstrate continuous compliance with the 
emission limitations, operating limits, and work practice standards?

* * * * *
    (e) * * *
    (9) Prior to January 1, 2024, report the tune-up date 
electronically, in a PDF file, in your semiannual compliance report, as 
specified in Sec.  63.10031(f)(4) and (6) and, if requested by the 
Administrator, in hard copy, as specified in Sec.  63.10031(f)(5). On 
and after January 1, 2024, report the tune-up date electronically in 
your quarterly compliance report, in accordance with Sec.  63.10031(g) 
and section 10.2 of appendix E to this subpart. The tune-up report date 
is the date when tune-up requirements in paragraphs (e)(6) and (7) of 
this section are completed.
    (f) You must submit the applicable reports and notifications 
required under Sec.  63.10031(a) through (k) to the Administrator 
electronically, using EPA's Emissions Collection and Monitoring Plan 
System (ECMPS) Client Tool. If the final date of any time period (or 
any deadline) for any of these submissions falls on a weekend or a 
Federal holiday, the time period shall be extended to the next business 
day. Moreover, if the EPA Host System supporting the ECMPS Client Tool 
is offline and unavailable for submission of reports for any part of a 
day when a report would otherwise be due, the deadline for reporting is 
automatically extended until the first business day on which the system 
becomes available following the outage. Use of the ECMPS Client Tool to 
submit a report or notification required under this subpart satisfies 
any requirement under subpart A of this part to submit that same report 
or notification (or the information contained in it) to the appropriate 
EPA Regional Office or State agency whose delegation request has been 
approved.
* * * * *
    (i) If you are relying on paragraph (2) of the definition of 
``startup'' in Sec.  63.10042, you must provide reports concerning 
activities and periods of startup and shutdown that occur on or prior 
to January 1, 2024, in accordance with Sec.  63.10031(c)(5), in your 
semiannual compliance report. For startup and shutdown incidents that 
occur on and after January 1, 2024, you must provide the applicable 
information referenced in Sec. Sec.  63.10031(c)(5)(ii) and 63.10020(e) 
quarterly, in PDF files, in accordance with Sec.  63.10031(i).
0
8. Section 63.10030 is amended by:
0
a. Revising the last sentence in paragraph (e) introductory text and 
paragraph (e)(7) introductory text;
0
b. Removing and reserving paragraph (e)(7)(i);
0
c. Revising paragraphs (e)(7)(iii) introductory text and 
(e)(7)(iii)(A)(3);
0
d. Adding in paragraph (e)(7)(iii)(B) the word ``must'' after the word 
``You''; and
0
e. Adding in paragraph (e)(7)(iii)(C) the word ``must'' after the word 
``you''.
    The revisions read as follows:


Sec.  63.10030  What notifications must I submit and when?

* * * * *
    (e) * * * The Notification of Compliance Status report must contain 
all of the information specified in paragraphs (e)(1) through (8) of 
this section that applies to your initial compliance strategy.
* * * * *
    (7) Except for requests to switch from one emission limit to 
another, as provided in paragraph (e)(7)(iii) of this section, your 
initial notification of compliance status shall also include the 
following information:
* * * * *
    (iii) For each of your existing EGUs, identification of each 
emissions limit specified in Table 2 to this subpart with which you 
plan to comply initially. (Note: If, at some future date, you wish to 
switch from the limit specified in your initial notification of 
compliance status, you must follow the procedures and meet the 
conditions of paragraphs (e)(7)(iii)(A) through (C) of this section.)
    (A) * * *
    (3) Your request includes performance stack test results or valid 
CMS data, obtained within 45 days prior to the date of your submission, 
demonstrating that each EGU or EGU emissions averaging group is in 
compliance with both the mass per heat input limit and the mass per 
gross output limit;
* * * * *
0
9. Section 63.10031 is amended by:
0
a. Revising paragraphs (a), (b) introductory text, (b)(1), (2), (4), 
and (5), and (c) introductory text;
0
b. Removing paragraphs (c)(5)(iii), (iv), and (v);
0
c. Adding paragraph (c)(10);
0
d. Revising paragraphs (d), (e), (f) introductory text, and (f)(1) and 
(2);
0
e. Removing and reserving paragraph (f)(3);
0
f. Revising paragraphs (f)(4), (f)(6) introductory text, (f)(6)(vii) 
and (xi), and (g); and
0
g. Adding paragraphs (h) through (k).
    The revisions and additions read as follows:


Sec.  63.10031   What reports must I submit and when?

    (a) You must submit each report in this section that applies to 
you.
    (1) If you are required to (or elect to) monitor Hg emissions 
continuously, you must meet the electronic reporting requirements of 
appendix A to this subpart.
    (2) If you elect to monitor HCl and/or HF emissions continuously, 
you must meet the electronic reporting requirements of appendix B to 
this subpart. Notwithstanding the requirement in this paragraph (a)(2), 
if you opt to certify your HCl monitor according to Performance 
Specification 18 in appendix B to part 60 of this chapter and to use 
Procedure 6 in appendix F to part 60 of this chapter for on-going QA of 
the monitor, then, on and prior to December 31, 2023, report only 
hourly HCl emissions data and the results of daily calibration drift 
tests and RATAs performed on or prior to that date; keep records of all 
of the other required certification and QA tests and report them, 
starting in 2024.
    (3) If you elect to monitor filterable PM emissions continuously, 
you must meet the electronic reporting requirements of appendix C to 
this subpart. Electronic reporting of hourly PM emissions data shall 
begin with the later of: The first operating hour on or after January 
1, 2024; or the first operating hour after completion of the initial PM 
CEMS correlation test.
    (4) If you elect to demonstrate continuous compliance using a PM 
CPMS, you must meet the electronic reporting requirements of appendix D 
to this subpart. Electronic reporting of the hourly PM CPMS output 
shall begin

[[Page 20359]]

with the later of: The first operating hour on or after January 1, 
2024; or the first operating hour after completion of the initial 
performance stack test that establishes the operating limit for the PM 
CPMS.
    (5) If you elect to monitor SO2 emission rate 
continuously as a surrogate for HCl, you must use the ECMPS Client Tool 
to submit the following information to EPA (except where it is already 
required to be reported or has been previously provided under the Acid 
Rain Program or another emissions reduction program that requires the 
use of part 75 of this chapter):
    (i) Monitoring plan information for the SO2 CEMS and for 
any additional monitoring systems that are required to convert 
SO2 concentrations to units of the emission standard, in 
accordance with Sec. Sec.  75.62 and 75.64(a)(4) of this chapter;
    (ii) Certification, recertification, quality-assurance, and 
diagnostic test results for the SO2 CEMS and for any 
additional monitoring systems that are required to convert 
SO2 concentrations to units of the emission standard, in 
accordance with Sec.  75.64(a)(5) of this chapter; and
    (iii) Quarterly electronic emissions reports. You must submit an 
electronic quarterly report within 30 days after the end of each 
calendar quarter, starting with a report for the calendar quarter in 
which the initial 30 boiler operating day performance test begins. Each 
report must include the following information:
    (A) The applicable operating data specified in Sec.  75.57(b) of 
this chapter;
    (B) An hourly data stream for the unadjusted SO2 
concentration (in ppm, rounded to one decimal place), and separate 
unadjusted hourly data streams for the other parameters needed to 
convert the SO2 concentrations to units of the standard. 
(Note: If a default moisture value is used in the emission rate 
calculations, an hourly data stream is not required for moisture; 
rather, the default value must be reported in the electronic monitoring 
plan.);
    (C) An hourly SO2 emission rate data stream, in units of 
the standard (i.e., lb/MMBtu or lb/MWh, as applicable), calculated 
according to Sec.  63.10007(e) and (f)(1), rounded to the same 
precision as the emission standard (i.e., with one leading non-zero 
digit and one decimal place), expressed in scientific notation. Use the 
following rounding convention: If the digit immediately following the 
first decimal place is 5 or greater, round the first decimal place 
upward (increase it by one); if the digit immediately following the 
first decimal place is 4 or less, leave the first decimal place 
unchanged;
    (D) The results of all required daily quality-assurance tests of 
the SO2 monitor and the additional monitors used to convert 
SO2 concentration to units of the standard, as specified in 
appendix B to part 75 of this chapter; and
    (E) A compliance certification, which includes a statement, based 
on reasonable inquiry of those persons with primary responsibility for 
ensuring that all SO2 emissions from the affected EGUs under 
this subpart have been correctly and fully monitored, by a responsible 
official with that official's name, title, and signature, certifying 
that, to the best of his or her knowledge, the report is true, 
accurate, and complete. You must submit such a compliance certification 
statement in support of each quarterly report.
    (b) You must submit semiannual compliance reports according to the 
requirements in paragraphs (b)(1) through (5) of this section.
    (1) The first compliance report must cover the period beginning on 
the compliance date that is specified for your affected source in Sec.  
63.9984 (or, if applicable, the extended compliance date approved under 
Sec.  63.6(i)(4)) and ending on June 30 or December 31, whichever date 
is the first date that occurs at least 180 days after the compliance 
date that is specified for your source in Sec.  63.9984 (or, if 
applicable, the extended compliance date approved under Sec.  
63.6(i)(4)).
    (2) The first compliance report must be submitted electronically no 
later than July 31 or January 31, whichever date is the first date 
following the end of the first calendar half after the compliance date 
that is specified for your source in Sec.  63.9984 (or, if applicable, 
the extended compliance date approved under Sec.  63.6(i)(4)).
* * * * *
    (4) Each subsequent compliance report must be submitted 
electronically no later than July 31 or January 31, whichever date is 
the first date following the end of the semiannual reporting period.
    (5) The final semiannual compliance report shall cover the 
reporting period from July 1, 2023 through December 31, 2023. Quarterly 
compliance reports shall be submitted thereafter, in accordance with 
paragraph (g) of this section, starting with a report covering the 
first calendar quarter of 2024.
    (c) The semiannual compliance report must contain the information 
required in paragraphs (c)(1) through (10) of this section.
* * * * *
    (10) If you had any process or control equipment malfunction(s) 
during the reporting period, you must include the number, duration, and 
a brief description for each type of malfunction which occurred during 
the semiannual reporting period which caused or may have caused any 
applicable emission limitation to be exceeded.
    (d) For EGUs whose owners or operators rely on a CMS to comply with 
an emissions or operating limit, the semiannual compliance reports 
described in paragraph (c) of this section must include the excess 
emissions and monitor downtime summary report described in Sec.  
63.10(e)(3)(vi). However, starting with the first calendar quarter of 
2024, reporting of the information under Sec.  63.10(e)(3)(vi) (and 
under paragraph (e)(3)(v), if the applicable excess emissions and/or 
monitor downtime threshold is exceeded) is discontinued for all CMS, 
and you must, instead, include in the quarterly compliance reports 
described in paragraph (g) of this section the applicable data elements 
in section 13 of appendix E to this subpart for any ``deviation'' (as 
defined in Sec.  63.10042 and elsewhere in this subpart) that occurred 
during the calendar quarter. If there were no deviations, you must 
include a statement to that effect in the quarterly compliance report.
    (e) Each affected source that has obtained a title V operating 
permit pursuant to part 70 or 71 of this chapter must report all 
deviations as defined in this subpart in the semiannual monitoring 
report required by 40 CFR 70.6(a)(3)(iii)(A) or 71.6(a)(3)(iii)(A). If 
an affected source submits a semiannual compliance report pursuant 
paragraphs (c) and (d) of this section, or two quarterly compliance 
reports covering the appropriate calendar half pursuant to paragraph 
(g) of this section, along with, or as part of, the semiannual 
monitoring report required by 40 CFR 70.6(a)(3)(iii)(A) or 
71.6(a)(3)(iii)(A), and the compliance report(s) includes all required 
information concerning deviations from any emission limit, operating 
limit, or work practice requirement in this subpart, submission of the 
compliance report(s) satisfies any obligation to report the same 
deviations in the semiannual monitoring report. Submission of the 
compliance report(s) does not otherwise affect any obligation the 
affected source may have to report deviations from permit requirements 
to the permit authority.
    (f) For each performance stack test completed prior to January 1, 
2024 (including 30- (or 90-) boiler operating day Hg LEE demonstration 
tests and PM

[[Page 20360]]

tests to establish operating limits for PM CPMS), you must submit a PDF 
test report in accordance with paragraph (f)(6) of this section, no 
later than 60 days after the date on which the testing is completed. 
For each test completed on or after January 1, 2024, in accordance with 
Sec.  63.10031(g), submit the applicable reference method information 
in sections 17 through 31 of appendix E to this subpart along with the 
quarterly compliance report for the calendar quarter in which the test 
was completed.
    (1) For each relative accuracy test audit (RATA) of an Hg, HCl, HF, 
or SO2 monitoring system completed prior to January 1, 2024, 
and for each PM CEMS correlation test, each relative response audit 
(RRA) and each response correlation audit (RCA) of a PM CEMS completed 
prior to that date, you must submit a PDF test report in accordance 
with paragraph (f)(6) of this section, no later than 60 days after the 
date on which the test is completed. For each SO2 or Hg RATA 
completed on or after January 1, 2024, you must submit the applicable 
reference method information in sections 17 through 31 of appendix E to 
this subpart prior to or concurrent with the relevant quarterly 
emissions report. For HCl or HF RATAs, and for correlation tests, RRAs, 
and RCAs of PM CEMS that are completed on or after January 1, 2024, 
submit the appendix E reference method information together with the 
summarized electronic test results, in accordance with section 11.4 of 
appendix B to this subpart or section 7.2.4 of appendix C to this part, 
as applicable.
    (2) If, for a particular EGU or a group of EGUs serving a common 
stack, you have elected to demonstrate compliance using a PM CEMS, an 
approved HAP metals CEMS, or a PM CPMS, you must submit quarterly PDF 
reports in accordance with paragraph (f)(6) of this section, which 
include all of the 30-boiler operating day rolling average emission 
rates derived from the CEMS data or the 30-boiler operating day rolling 
average responses derived from the PM CPMS data (as applicable). The 
quarterly reports are due within 60 days after the reporting periods 
ending on March 31st, June 30th, September 30th, and December 31st. 
Submission of these quarterly reports in PDF files shall end with the 
report that covers the fourth calendar quarter of 2023. Beginning with 
the first calendar quarter of 2024, the compliance averages shall no 
longer be reported separately, but shall be incorporated into the 
quarterly compliance reports described in paragraph (g) of this 
section. In addition to the compliance averages for PM CEMS, PM CPMS, 
and/or HAP metals CEMS, the quarterly compliance reports described in 
paragraph (g) of this section must also include the 30- (or, if 
applicable 90-) boiler operating day rolling average emission rates for 
Hg, HCl, HF, and/or SO2, if you have elected to (or are 
required to) continuously monitor these pollutants. Further, if your 
EGU or common stack is in an averaging plan, your quarterly compliance 
reports must identify all of the EGUs or common stacks in the plan and 
must include all of the 30- (or 90-) group boiler operating day rolling 
weighted average emission rates (WAERs) for the averaging group.
* * * * *
    (4) You must submit semiannual compliance reports as required under 
paragraphs (b) through (d) of this section, ending with a report 
covering the semiannual period from July 1 through December 31, 2023, 
and Notifications of Compliance Status as required under Sec.  
63.10030(e), as PDF files. Quarterly compliance reports shall be 
submitted in XML format thereafter, in accordance with paragraph (g) of 
this section, starting with a report covering the first calendar 
quarter of 2024.
* * * * *
    (6) All reports and notifications described in paragraphs (f) 
introductory text and (f)(1), (2), and (4) of this section shall be 
submitted to the EPA in the specified format and at the specified 
frequency, using the ECMPS Client Tool. Each PDF version of a stack 
test report, CEMS RATA report, PM CEMS correlation test report, RRA 
report, and RCA report must include sufficient information to assess 
compliance and to demonstrate that the reference method testing was 
done properly. Note that EPA will continue to accept, as necessary, PDF 
reports that are being phased out at the end of 2023, if the submission 
deadlines for those reports extend beyond December 31, 2023. The 
following data elements must be entered into the ECMPS Client Tool at 
the time of submission of each PDF file:
* * * * *
    (vii) An indication of the type of PDF report or notification being 
submitted;
* * * * *
    (xi) The date the performance test was completed (if applicable) 
and the test number (if applicable); and
* * * * *
    (g) Starting with a report for the first calendar quarter of 2024, 
you must use the ECMPS Client Tool to submit quarterly electronic 
compliance reports. Each quarterly compliance report shall include the 
applicable data elements in sections 2 through 13 of appendix E to this 
subpart. For each stack test summarized in the compliance report, you 
must also submit the applicable reference method information in 
sections 17 through 31 of appendix E to this subpart. The compliance 
reports and associated appendix E information must be submitted no 
later than 60 days after the end of each calendar quarter.
    (h) On and after January 1, 2024, initial Notifications of 
Compliance Status (if any) shall be submitted in accordance with Sec.  
63.9(h)(2)(ii), as PDF files, using the ECMPS Client Tool. The 
applicable data elements in paragraphs (f)(6)(i) through (xii) of this 
section must be entered into ECMPS with each Notification.
    (i) If you have elected to use paragraph (2) of the definition of 
``startup'' in Sec.  63.10042, then, for startup and shutdown incidents 
that occur on or prior to December 31, 2023, you must include the 
information in Sec.  63.10031(c)(5) in the semiannual compliance 
report, in a PDF file. If you have elected to use paragraph (2) of the 
definition of ``startup'' in Sec.  63.10042, then, for startup and 
shutdown event(s) that occur on or after January 1, 2024, you must use 
the ECMPS Client Tool to submit the information in Sec. Sec.  
63.10031(c)(5) and 63.10020(e) along with each quarterly compliance 
report, in a PDF file, starting with a report for the first calendar 
quarter of 2024. The applicable data elements in paragraphs (f)(6)(i) 
through (xii) of this section must be entered into ECMPS with each 
startup and shutdown report.
    (j) If you elect to use a certified PM CEMS to monitor PM emissions 
continuously to demonstrate compliance with this subpart and have begun 
recording valid data from the PM CEMS prior to [DATE 60 DAYS AFTER DATE 
OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], you must use 
the ECMPS Client Tool to submit a detailed report of your PS 11 
correlation test (see appendix B to part 60 of this chapter) in a PDF 
file no later than 60 days after that date. For a correlation test 
completed on or after [DATE 60 DAYS AFTER DATE OF PUBLICATION OF THE 
FINAL RULE IN THE FEDERAL REGISTER], but prior to January 1, 2024, you 
must submit the PDF report no later than 60 days after the date on 
which the test is completed. For a correlation test completed on or 
after January 1, 2024, you must submit the PDF report according to 
section 7.2.4 of appendix C to this subpart. The applicable data 
elements in paragraphs (f)(6)(i) through (xii) of this section must

[[Page 20361]]

be entered into ECMPS with the PDF report.
    (k) If you elect to demonstrate compliance using a PM CPMS or an 
approved HAP metals CEMS, you must submit quarterly reports of your QA/
QC activities (e.g., calibration checks, performance audits), in a PDF 
file, beginning with a report for the first quarter of 2024, if the PM 
CPMS or HAP metals CEMS is used for the compliance demonstration in 
that quarter. Otherwise, submit a report for the first calendar quarter 
in which the PM CPMS or HAP metals CEMS is used to demonstrate 
compliance. These reports are due no later than 60 days after the end 
of each calendar quarter. The applicable data elements in paragraphs 
(f)(6)(i) through (xii) of this section must be entered into ECMPS with 
the PDF report.
0
10. Section 63.10032 is amended by revising paragraphs (a) introductory 
text and (a)(1) to read as follows:


Sec.  63.10032   What records must I keep?

    (a) You must keep records according to paragraphs (a)(1) and (2) of 
this section. If you are required to (or elect to) continuously monitor 
Hg and/or HCl and/or HF and/or PM emissions, or if you elect to use a 
PM CPMS, you must keep the records required under appendix A and/or 
appendix B and/or appendix C and/or appendix D to this subpart. If you 
elect to conduct periodic (e.g., quarterly or annual) performance stack 
tests, then, for each test completed on or after January 1, 2024, you 
must keep records of the applicable data elements under Sec.  63.7(g). 
You must also keep records of all data elements and other information 
in appendix E to this subpart that apply to your compliance strategy.
    (1) In accordance with Sec.  63.10(b)(2)(xiv), a copy of each 
notification or report that you submit to comply with this subpart. You 
must also keep records of all supporting documentation for the initial 
Notifications of Compliance Status, semiannual compliance reports, or 
quarterly compliance reports that you submit.
* * * * *
0
11. Section 63.10042 is amended by:
0
a. In the definition ``Diluent cap,'' adding ``PM,'' after ``HF,'';
0
b. In the definition ``Monitoring system malfunction or out of control 
period,'' removing the words ``or out of control period''; and
0
c. Adding the definition ``Out of control period'' in alphabetical 
order.
    The addition reads as follows:


Sec.  63.10042  What definitions apply to this subpart?

* * * * *
    Out-of-control period, as it pertains to continuous monitoring 
systems, means any period:
    (1) Beginning with the hour corresponding to the completion of a 
daily calibration or quality assurance audit that indicates that the 
instrument fails to meet the applicable acceptance criteria; and
    (2) Ending with the hour corresponding to the completion of an 
additional calibration or quality assurance audit following corrective 
action showing that the instrument meets the applicable acceptance 
criteria.
* * * * *
0
12. Table 3 to subpart UUUUU is amended by revising the entries ``3. A 
coal-fired, liquid oil-fired (excluding limited-use liquid oil-fired 
subcategory units), or solid oil-derived fuel-fired EGU during 
startup'' and ``4. A coal-fired, liquid oil-fired (excluding limited-
use liquid oil-fired subcategory units), or solid oil-derived fuel-
fired EGU during shutdown'' to read as follows:

                          Table 3 to Subpart UUUUU of Part 63--Work Practice Standards
                                                [ * * * * * * * ]
----------------------------------------------------------------------------------------------------------------
            If your EGU is . . .                               You must meet the following . . .
----------------------------------------------------------------------------------------------------------------
 
                                                  * * * * * * *
3. A coal-fired, liquid oil-fired (excluding  a. You have the option of complying using either of the following
 limited-use liquid oil-fired subcategory      work practice standards:
 units), or solid oil-derived fuel-fired EGU  (1) If you choose to comply using paragraph (1) of the definition
 during startup.                               of ``startup'' in Sec.   63.10042, you must operate all CMS
                                               during startup. Startup means either the first-ever firing of
                                               fuel in a boiler for the purpose of producing electricity, or the
                                               firing of fuel in a boiler after a shutdown event for any
                                               purpose. Startup ends when any of the steam from the boiler is
                                               used to generate electricity for sale over the grid or for any
                                               other purpose (including on site use). For startup of a unit, you
                                               must use clean fuels as defined in Sec.   63.10042 for ignition.
                                               Once you convert to firing coal, residual oil, or solid oil-
                                               derived fuel, you must engage all of the applicable control
                                               technologies except dry scrubber and SCR. You must start your dry
                                               scrubber and SCR systems, if present, appropriately to comply
                                               with relevant standards applicable during normal operation. You
                                               must comply with all applicable emissions limits at all times
                                               except for periods that meet the applicable definitions of
                                               startup and shutdown in this subpart. You must keep records
                                               during startup periods. You must provide reports concerning
                                               activities and startup periods, as specified in Sec.
                                               63.10011(g) and Sec.   63.10021(h) and (i). If you elect to use
                                               paragraph (2) of the definition of ``startup'' in Sec.
                                               63.10042, you must report the applicable information in Sec.
                                               63.10031(c)(5) concerning startup periods as follows: for startup
                                               periods that occur on or prior to December 31, 2023 in PDF files
                                               in the semiannual compliance report; for startup periods that
                                               occur on or after January 1, 2024, quarterly, in PDF files,
                                               according to Sec.   63.10031(i).
                                              (2) If you choose to comply using paragraph (2) of the definition
                                               of ``startup'' in Sec.   63.10042, you must operate all CMS
                                               during startup. You must also collect appropriate data, and you
                                               must calculate the pollutant emission rate for each hour of
                                               startup.
                                              For startup of an EGU, you must use one or a combination of the
                                               clean fuels defined in Sec.   63.10042 to the maximum extent
                                               possible, taking into account considerations such as boiler or
                                               control device integrity, throughout the startup period. You must
                                               have sufficient clean fuel capacity to engage and operate your PM
                                               control device within one hour of adding coal, residual oil, or
                                               solid oil-derived fuel to the unit. You must meet the startup
                                               period work practice requirements as identified in Sec.
                                               63.10020(e).
                                              Once you start firing coal, residual oil, or solid oil-derived
                                               fuel, you must vent emissions to the main stack(s). You must
                                               comply with the applicable emission limits beginning with the
                                               hour after startup ends. You must engage and operate your
                                               particulate matter control(s) within 1 hour of first firing of
                                               coal, residual oil, or solid oil-derived fuel.
                                              You must start all other applicable control devices as
                                               expeditiously as possible, considering safety and manufacturer/
                                               supplier recommendations, but, in any case, when necessary to
                                               comply with other standards made applicable to the EGU by a
                                               permit limit or a rule other than this Subpart that require
                                               operation of the control devices.

[[Page 20362]]

 
                                              b. Relative to the syngas not fired in the combustion turbine of
                                               an IGCC EGU during startup, you must either: (1) Flare the
                                               syngas, or (2) route the syngas to duct burners, which may need
                                               to be installed, and route the flue gas from the duct burners to
                                               the heat recovery steam generator.
                                              c. If you choose to use just one set of sorbent traps to
                                               demonstrate compliance with the applicable Hg emission limit, you
                                               must comply with the limit at all times; otherwise, you must
                                               comply with the applicable emission limit at all times except for
                                               startup and shutdown periods.
                                              d. You must collect monitoring data during startup periods, as
                                               specified in Sec.   63.10020(a) and (e). You must keep records
                                               during startup periods, as provided in Sec.  Sec.   63.10032 and
                                               63.10021(h). You must provide reports concerning activities and
                                               startup periods, as specified in Sec.  Sec.   63.10011(g),
                                               63.10021(i), and 63.10031. If you elect to use paragraph (2) of
                                               the definition of ``startup'' in Sec.   63.10042, you must report
                                               the applicable information in Sec.   63.10031(c)(5) concerning
                                               startup periods as follows: for startup periods that occur on or
                                               prior to December 31, 2023, in PDF files in the semiannual
                                               compliance report; for startup periods that occur on or after
                                               January 1, 2024, quarterly, in PDF files, according to Sec.
                                               63.10031(i).
4. A coal-fired, liquid oil-fired (excluding  You must operate all CMS during shutdown. You must also collect
 limited-use liquid oil-fired subcategory      appropriate data, and you must calculate the pollutant emission
 units), or solid oil-derived fuel-fired EGU   rate for each hour of shutdown for those pollutants for which a
 during shutdown.                              CMS is used.
                                              While firing coal, residual oil, or solid oil-derived fuel during
                                               shutdown, you must vent emissions to the main stack(s) and
                                               operate all applicable control devices and continue to operate
                                               those control devices after the cessation of coal, residual oil,
                                               or solid oil-derived fuel being fed into the EGU and for as long
                                               as possible thereafter considering operational and safety
                                               concerns. In any case, you must operate your controls when
                                               necessary to comply with other standards made applicable to the
                                               EGU by a permit limit or a rule other than this Subpart and that
                                               require operation of the control devices.
                                              If, in addition to the fuel used prior to initiation of shutdown,
                                               another fuel must be used to support the shutdown process, that
                                               additional fuel must be one or a combination of the clean fuels
                                               defined in Sec.   63.10042 and must be used to the maximum extent
                                               possible, taking into account considerations such as not
                                               compromising boiler or control device integrity.
                                              Relative to the syngas not fired in the combustion turbine of an
                                               IGCC EGU during shutdown, you must either: (1) Flare the syngas,
                                               or (2) route the syngas to duct burners, which may need to be
                                               installed, and route the flue gas from the duct burners to the
                                               heat recovery steam generator.
                                              You must comply with all applicable emission limits at all times
                                               except during startup periods and shutdown periods at which time
                                               you must meet this work practice. You must collect monitoring
                                               data during shutdown periods, as specified in Sec.   63.10020(a).
                                               You must keep records during shutdown periods, as provided in
                                               Sec.  Sec.   63.10032 and 63.10021(h). Any fraction of an hour in
                                               which shutdown occurs constitutes a full hour of shutdown. You
                                               must provide reports concerning activities and shutdown periods,
                                               as specified in Sec.  Sec.   63.10011(g), 63.10021(i), and
                                               63.10031. If you elect to use paragraph (2) of the definition of
                                               ``startup'' in Sec.   63.10042, you must report the applicable
                                               information in Sec.   63.10031(c)(5) concerning shutdown periods
                                               as follows: for shutdown periods that occur on or prior to
                                               December 31, 2023, in PDF files in the semiannual compliance
                                               report; for shutdown periods that occur on or after January 1,
                                               2024, quarterly, in PDF files, according to Sec.   63.10031(i).
----------------------------------------------------------------------------------------------------------------

0
13. Table 8 to subpart UUUUU is revised to read as follows:

       Table 8 to Subpart UUUUU of Part 63--Reporting Requirements
    [In accordance with Sec.   63.10031, you must meet the following
   reporting requirements, as they apply to your compliance strategy]
------------------------------------------------------------------------
               You must submit the following reports . . .
-------------------------------------------------------------------------
1. The electronic reports required under Sec.   63.10031(a)(1), if you
 continuously monitor Hg emissions.
2. The electronic reports required under Sec.   63.10031(a)(2), if you
 continuously monitor HCl and/or HF emissions.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.
3. The electronic reports required under Sec.   63.10031(a)(3), if you
 continuously monitor PM emissions.
    Reporting of hourly PM emissions data using ECMPS shall begin with
     the first operating hour after: January 1, 2024 or the hour of
     completion of the initial PM CEMS correlation test, whichever is
     later.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.
4. The electronic reports required under Sec.   63.10031(a)(4), if you
 elect to use a PM CPMS.
    Reporting of hourly PM CPMS response data using ECMPS shall begin
     with the first operating hour after January 1, 2024 or the first
     operating hour after completion of the initial performance stack
     test that establishes the operating limit for the PM CPMS,
     whichever is later.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.
5. The electronic reports required under Sec.   63.10031(a)(5), if you
 continuously monitor SO2 emissions.
    Where applicable, these reports are due no later than 30 days after
     the end of each calendar quarter.
6. PDF reports for all performance stack tests completed prior to
 January 1, 2024 (including 30- or 90-boiler operating day Hg LEE test
 reports and PM test reports to set operating limits for PM CPMS),
 according to Sec.   63.10031(f) introductory text and (f)(6).
    For each test, submit the PDF report no later than 60 days after the
     date on which testing is completed.
For a PM test that is used to set an operating limit for a PM CPMS, the
 report must also include the information in Sec.   63.10023(b)(2)(vi).
    For each performance stack test completed on or after January 1,
     2024, submit the test results in the relevant quarterly compliance
     report under Sec.   63.10031(g), together with the applicable
     reference method information in sections 17 through 31 of appendix
     E to this subpart.
7. PDF reports for all RATAs of Hg, HCl, HF, and/or SO2 monitoring
 systems completed prior to January 1, 2024, and for correlation tests,
 RRAs and/or RCAs of PM CEMS completed prior to January 1, 2024,
 according to Sec.   63.10031(f)(1) and (6).
    For each test, submit the PDF report no later than 60 days after the
     date on which testing is completed.

[[Page 20363]]

 
    For each SO2 or Hg system RATA completed on or after January 1,
     2024, submit the electronic test summary required by appendix A to
     this subpart or part 75 of this chapter (as applicable) together
     with the applicable reference method information in sections 17-30
     of appendix E to this subpart, either prior to or concurrent with
     the relevant quarterly emissions report.
    For each HCl or HF system RATA, and for each correlation test, RRA,
     and RCA of a PM CEMS completed on or after January 1, 2024, submit
     the electronic test summary in accordance with section 11.4 of
     appendix B to this subpart or section 7.2.4 of appendix C to this
     part, as applicable, together with the applicable reference method
     information in sections 17-30 of appendix E to this subpart.
8. Quarterly reports, in PDF files, that include all 30-boiler operating
 day rolling averages in the reporting period derived from your PM CEMS,
 approved HAP metals CEMS, and/or PM CPMS, according to Sec.
 63.10031(f)(2) and (6). These reports are due no later than 60 days
 after the end of each calendar quarter.
    The final quarterly rolling averages report in PDF files shall cover
     the fourth calendar quarter of 2023.
    Starting with the first quarter of 2024, you must report all 30-
     boiler operating day rolling averages for PM CEMS, approved HAP
     metals CEMS, PM CPMS, Hg CEMS, Hg sorbent trap systems, HCl CEMS,
     HF CEMS, and/or SO2 CEMS (or 90-boiler operating day rolling
     averages for Hg systems), in XML format, in the quarterly
     compliance reports required under Sec.   63.10031(g).
    If your EGU or common stack is in an averaging plan, each quarterly
     compliance report must identify the EGUs in the plan and include
     all of the 30- or 90- group boiler operating day weighted average
     emission rates (WAERs) for the averaging group.
    The quarterly compliance reports must be submitted no later than 60
     days after the end of each calendar quarter.
9. The semiannual compliance reports described in Sec.   63.10031(c) and
 (d), in PDF files, according to Sec.   63.10031(f)(4) and (6). The due
 dates for these reports are specified in Sec.   63.10031(b).
    The final semiannual compliance report shall cover the period from
     July 1, 2023 through December 31, 2023.
10. Notifications of compliance status, in PDF files, according to Sec.
  63.10031(f)(4) and (6) until December 31, 2023, and according to Sec.
  63.10031(h) thereafter.
11. Quarterly electronic compliance reports, in accordance with Sec.
 63.10031(g), starting with a report for the first calendar quarter of
 2024. The reports must be in XML format and must include the applicable
 data elements in sections 2 through 13 of appendix E to this subpart.
    These reports are due no later than 60 days after the end of each
     calendar quarter.
12. Quarterly reports, in PDF files, that include the applicable
 information in Sec.  Sec.   63.10031(c)(5)(ii) and 63.10020(e)
 pertaining to startup and shutdown events, starting with a report for
 the first calendar quarter of 2024, if you have elected to use
 paragraph (2) of the definition of ``startup'' in Sec.   63.10042 (see
 Sec.   63.10031(i)).
    These PDF reports shall be submitted no later than 60 days after the
     end of each calendar quarter, along with the quarterly compliance
     reports required under Sec.   63.10031(g).
13. A test report for the PS 11 correlation test (see appendix B to part
 60 of this chapter) of your PM CEMS, in accordance with Sec.
 63.10031(j).
    If, prior to [DATE 60 DAYS AFTER DATE OF PUBLICATION OF THE FINAL
     RULE IN THE FEDERAL REGISTER], you have begun using a certified PM
     CEMS to demonstrate compliance with this subpart, use the ECMPS
     Client Tool to submit the report, in a PDF file, no later than 60
     days after that date.
    For correlation tests completed on or after [DATE 60 DAYS AFTER DATE
     OF PUBLICATION OF THE FINAL RULE IN THE FEDERAL REGISTER], but
     prior to January 1, 2024, submit the report, in a PDF file, no
     later than 60 days after the date on which the test is completed.
    For correlation tests completed on or after January 1, 2024, submit
     the test results electronically, according to section 7.2.4 of
     appendix C to this subpart, together with the applicable reference
     method data in sections 17 through 31 of appendix E to this
     subpart.
14. Quarterly reports that include the QA/QC activities for your PM CPMS
 or approved HAP metals CEMS (as applicable), in PDF files, according to
 Sec.   63.10031(k).
    The first report shall cover the first calendar quarter of 2024, if
     the PM CPMS or HAP metals CEMS is in use during that quarter.
     Otherwise, reporting begins with the first calendar quarter in
     which the PM CPMS or HAP metals CEMS is used to demonstrate
     compliance.
    These reports are due no later than 60 days after the end of each
     calendar quarter.
------------------------------------------------------------------------

0
 14. Table 9 to subpart UUUUU is amended by:
0
a. Revising the entries ``Sec.  63.9'', ``Sec.  63.10(c)(7)'', and 
``Sec.  63.10(c)(8)''; and
0
b. Adding the entry ``Sec.  63.10(e)(3)(v) and (vi)'' in numerical 
order.
    The addition and revisions read as follows:
* * * * *

Table 9 to Subpart UUUUU of Part 63--Applicability of General Provisions
                            to Subpart UUUUU
                            [ * * * * * * * ]
------------------------------------------------------------------------
                                                     Applies to subpart
             Citation                  Subject              UUUUU
------------------------------------------------------------------------
 
                              * * * * * * *
Sec.   63.9......................  Notification     Yes, except (1) for
                                    Requirements.    the 60-day
                                                     notification prior
                                                     to conducting a
                                                     performance test in
                                                     Sec.   63.9(e);
                                                     instead use a 30-
                                                     day notification
                                                     period per Sec.
                                                     63.10030(d), (2)
                                                     the notification of
                                                     the CMS performance
                                                     evaluation in Sec.
                                                      63.9(g)(1) is
                                                     limited to RATAs,
                                                     and (3) the
                                                     information
                                                     required per Sec.
                                                     63.9(h)(2)(i);
                                                     instead provide the
                                                     applicable
                                                     information in Sec.
                                                       63.10030(e)(1)
                                                     through (e)(8), for
                                                     the initial
                                                     notification of
                                                     compliance status,
                                                     only.
 

[[Page 20364]]

 
                              * * * * * * *
Sec.   63.10(c)(7)...............  Additional       Applies only through
                                    recordkeeping    December 31, 2023.
                                    requirements
                                    for CMS--
                                    identifying
                                    exceedances
                                    and excess
                                    emissions.
Sec.   63.10(c)(8)...............  Additional       Applies only through
                                    recordkeeping    December 31, 2023.
                                    requirements
                                    for CMS--
                                    identifying
                                    exceedances
                                    and excess
                                    emissions.
 
                              * * * * * * *
Sec.   63.10(e)(3)(v) and (vi)...  Excess           Applies only through
                                    emissions and    December 31, 2023.
                                    continuous
                                    monitoring
                                    system
                                    performance
                                    reports.
 
                              * * * * * * *
------------------------------------------------------------------------

0
15. Appendix A to subpart UUUUU is amended by revising sections 
``7.1.3.3'', ``7.1.4.3'', ``7.1.8.2'' and ``7.2.3.1'' to read as 
follows:

Appendix A to Subpart UUUUU of Part 63--HG Monitoring Provisions

* * * * *

7. Recordkeeping and Reporting

* * * * *
    7.1.3.3 The hourly Hg concentration, if a quality-assured value 
is obtained for the hour ([micro]g/scm, with one leading non-zero 
digit and one decimal place, expressed in scientific notation). Use 
the following rounding convention: if the digit immediately 
following the first decimal place is 5 or greater, round the first 
decimal place upward (increase it by one); if the digit immediately 
following the first decimal place is 4 or less, leave the first 
decimal place unchanged;
* * * * *
    7.1.4.3 The hourly Hg concentration, if a quality-assured value 
is obtained for the hour ([micro]g/scm, with one leading non-zero 
digit and one decimal place, expressed in scientific notation). Use 
the following rounding convention: If the digit immediately 
following the first decimal place is 5 or greater, round the first 
decimal place upward (increase it by one); if the digit immediately 
following the first decimal place is 4 or less, leave the first 
decimal place unchanged. Note that when a single quality-assured Hg 
concentration value is obtained for a particular data collection 
period, that single concentration value is applied to each operating 
hour of the data collection period.
* * * * *
    7.1.8.2 The hourly Hg emissions rate (lb/TBtu or lb/GWh, as 
applicable), calculated according to section 6.2.1 or 6.2.2 of this 
appendix, rounded to the same precision as the standard (i.e., with 
one leading non-zero digit and one decimal place, expressed in 
scientific notation), if valid values of Hg concentration and all 
other required parameters (stack gas volumetric flow rate, diluent 
gas concentration, electrical load, and moisture data, as 
applicable) are obtained for the hour. Use the following rounding 
convention: If the digit immediately following the first decimal 
place is 5 or greater, round the first decimal place upward 
(increase it by one); if the digit immediately following the first 
decimal place is 4 or less, leave the first decimal place unchanged;
* * * * *
    7.2.3.1 For an EGU that begins reporting hourly Hg 
concentrations with a previously-certified Hg monitoring system, 
submit the monitoring plan information in section 7.1.1.2 of this 
appendix prior to or concurrent with the first required quarterly 
emissions report. For a new EGU, or for an EGU switching to 
continuous monitoring of Hg emissions after having implemented 
another allowable compliance option under this subpart, submit the 
information in section 7.1.1.2 of this appendix at least 21 days 
prior to the start of initial certification testing of the CEMS. 
Also submit the monitoring plan information in 40 CFR 75.53(g) 
pertaining to any required flow rate, diluent gas, and moisture 
monitoring systems within the applicable time frame specified in 
this section, if the required records are not already in place.
* * * * *
0
16. Appendix B to subpart UUUUU is amended by:
0
a. Revising the heading and introductory text of section 2.3 and 
sections ``9.4'', ``10.1.3.3'', ``10.1.7.2'', ``10.1.8.1.1'', 
``10.1.8.1.2'', and ``10.1.8.1.3'';
0
b. Adding sections ``10.1.8.1.4'' through ``10.1.8.1.12'' in numerical 
order;
0
c. Revising sections ``11.3.1'', ``11.4 introductory text'', and 
``11.4.1'';
0
d. Adding sections ``11.4.1.1'' through ``11.4.1.9'' in numerical 
order;
0
e. Revising sections ``11.4.2 introductory text'', ``11.4.3.11'', and 
``11.4.3.12'';
0
f. Redesignating section ``11.4.3.13'' as ``11.4.3.14'';
0
g. Adding new section ``11.4.3.13'';
0
h. Revising newly redesignated section ``11.4.3.14'';
0
i. Redesignating section ``11.4.4'' as ``11.4.13'';
0
j. Adding sections: ``11.4.4 introductory text''; ``11.4.4.1 through 
11.4.4.7''; ``11.4.5 introductory text''; ``11.4.5.1''; ``11.4.5.1.1 
through 11.4.5.1.9''; ``11.4.5.2 introductory text''; ``11.4.5.2.1 
through 11.4.5.2.6''; ``11.4.6 introductory text''; ``11.4.6.1 through 
11.4.6.8'', ``11.4.7 introductory text''; ``11.4.7.1 through 
11.4.7.6''; ``11.4.8 introductory text''; ``11.4.8.1 through 
11.4.8.15''; ``11.4.9 introductory text''; ``11.4.9.1 through 
11.4.9.5''; ``11.4.10 introductory text''; ``11.4.10.1 through 
11.4.10.8''; ``11.4.11 introductory text''; ``11.4.11.1 through 
11.4.11.7''; ``11.4.12 introductory text''; and ``11.4.12.1 through 
11.4.12.9''; and
0
k. Revising newly redesignated section ``11.4.13'' and section 
``11.5.1''.
    The revisions and additions read as follows:

Appendix B to Subpart UUUUU of Part 63--HCL and HF 
Monitoring Provisions

* * * * *

2. Monitoring of HCl and/or HF Emissions

* * * * *
    2.3 Monitoring System Equipment, Supplies, Definitions, and 
General Operation. The following provisions apply:
* * * * *

9. Data Reduction and Calculations

* * * * *
    9.4 Use Equation A-5 in appendix A of this subpart to calculate 
the required 30-boiler operating day rolling average HCl or HF 
emission rates. Report each 30-boiler operating day rolling average 
to the same precision as the standard (i.e., with one leading non-
zero digit and one decimal place), expressed in scientific notation. 
The

[[Page 20365]]

term Eho in Equation A-5 must be in the units of the 
applicable emissions limit.
* * * * *

10. Recordkeeping Requirements

* * * * *
    10.1.3.3 The pollutant concentration, for each hour in which a 
quality-assured value is obtained. For HCl and HF, record the data 
in parts per million (ppm), with one leading non-zero digit and one 
decimal place, expressed in scientific notation. Use the following 
rounding convention: If the digit immediately following the first 
decimal place is 5 or greater, round the first decimal place upward 
(increase it by one); if the digit immediately following the first 
decimal place is 4 or less, leave the first decimal place unchanged.
* * * * *
    10.1.7.2 The hourly HCl and/or HF emissions rate (lb/MMBtu, or 
lb/MWh, as applicable), for each hour in which valid values of HCl 
or HF concentration and all other required parameters (stack gas 
volumetric flow rate, diluent gas concentration, electrical load, 
and moisture data, as applicable) are obtained for the hour. Round 
off the emission rate to the same precision as the standard (i.e., 
with one leading non-zero digit and one decimal place, expressed in 
scientific notation). Use the following rounding convention: If the 
digit immediately following the first decimal place is 5 or greater, 
round the first decimal place upward (increase it by one); if the 
digit immediately following the first decimal place is 4 or less, 
leave the first decimal place unchanged;
* * * * *
    10.1.8.1.1 For each required 7-day and daily calibration drift 
test or daily calibration error test (including daily calibration 
transfer standard tests) of the HCl or HF CEMS, record the test 
date(s) and time(s), reference gas value(s), monitor response(s), 
and calculated calibration drift or calibration error value(s). If 
you use the dynamic spiking option for the mid-level calibration 
drift check under PS 18 of appendix B to part 60 of this chapter, 
you must also record the measured concentration of the native HCl in 
the flue gas before and after the spike and the spiked gas dilution 
factor. When using an IP-CEMS under PS 18, you must also record the 
measured concentrations of the native HCl before and after 
introduction of each reference gas, the path lengths of the 
calibration cell and the stack optical path, the stack and 
calibration cell temperatures, the instrument line strength factor, 
and the calculated equivalent concentration of reference gas.
    10.1.8.1.2 For the required gas audits of an FTIR HCl or HF CEMS 
that is following PS 15 of appendix B to part 60 of this chapter, 
record the date and time of each spiked and unspiked sample, the 
audit gas reference values and uncertainties. Keep records of all 
calculations and data analyses required under sections 9.1 and 12.1 
of Performance Specification (PS) 15, and the results of those 
calculations and analyses.
    10.1.8.1.3 For each required RATA of an HCl or HF CEMS, record 
the beginning and ending date and time of each test run, the 
reference method(s) used, and the reference method and HCl or HF 
CEMS run values. Keep records of stratification tests performed (if 
any), all of the raw field data, relevant process operating data, 
and all of the calculations used to determine the relative accuracy.
    10.1.8.1.4 For each required beam intensity test of an HCl IP-
CEMS under PS 18 of appendix B to part 60 of this chapter, record 
the test date and time, the known attenuation value (%) used for the 
test, the concentration of the high-level reference gas used, the 
full-beam and attenuated beam intensity levels, the measured HCl 
concentrations at full-beam intensity and attenuated intensity and 
the percent difference between them, and the results of the test. 
For each required daily beam intensity check of an IP-CEMS under 
Procedure 6 of appendix F to part 60 of this chapter, record the 
beam intensity measured including the units of measure and the 
results of the check.
    10.1.8.1.5 For each required measurement error test of an HCl 
monitor, record the date and time of each gas injection, the 
reference gas concentration (low, mid, or high) and the monitor 
response for each of the three injections at each of the three 
levels. Also record the average monitor response and the measurement 
error (ME) at each gas level and the related calculations. For 
measurement error tests conducted on IP-CEMS, also record the 
measured concentrations of the native HCl before and after 
introduction of each reference gas, the path lengths of the 
calibration cell and the stack optical path, the stack and 
calibration cell temperatures, the stack and calibration cell 
pressures, the instrument line strength factor, and the calculated 
equivalent concentration of reference gas.
    10.1.8.1.6 For each required level of detection (LOD) test of an 
HCl monitor performed in a controlled environment, record the test 
date, the concentrations of the reference gas and interference 
gases, the results of the seven (or more) consecutive measurements 
of HCl, the standard deviation, and the LOD value. For each required 
LOD test performed in the field, record the test date, the three 
measurements of the native source HCl concentration, the results of 
the three independent standard addition (SA) measurements known as 
standard addition response (SAR), the effective spike addition gas 
concentration (for IP-CEMS, the equivalent concentration of the 
reference gas), the resulting standard addition detection level 
(SADL) value and all related calculations. For extractive CEMS 
performing the SA using dynamic spiking, you must record the spiked 
gas dilution factor.
    10.1.8.1.7 For each required measurement error/level of 
detection response time test of an HCl monitor, record the test 
date, the native HCl concentration of the flue gas, the reference 
gas value, the stable reference gas readings, the upscale/downscale 
start and end times, and the results of the upscale and downscale 
stages of the test.
    10.1.8.1.8 For each required temperature or pressure measurement 
verification or audit of an IP-CEMS, keep records of the test date, 
the temperatures or pressures (as applicable) measured by the 
calibrated temperature or pressure reference device and the IP-CEMS, 
and the results of the test.
    10.1.8.1.9 For each required interference test of an HCl 
monitor, record (or obtain from the analyzer manufacturer records 
of): The date of the test; the gas volume/rate, temperature, and 
pressure used to conduct the test; the HCl concentration of the 
reference gas used; the concentrations of the interference test 
gases; the baseline HCl and HCl responses for each interferent 
combination spiked; and the total percent interference as a function 
of span or HCl concentration.
    10.1.8.1.10 For each quarterly relative accuracy audit (RAA) of 
an HCl monitor, record the beginning and ending date and time of 
each test run, the reference method used, the HCl concentrations 
measured by the reference method and CEMS for each test run, the 
average concentrations measured by the reference method and the 
CEMS, and the calculated relative accuracy (RA). Keep records of the 
raw field data, relevant process operating data, and the 
calculations used to determine the RA.
    10.1.8.1.11 For each quarterly cylinder gas audit (CGA) of an 
HCl monitor, record the date and time of each injection, and the 
reference gas concentration (zero, mid, or high) and the monitor 
response for each injection. Also record the average monitor 
response and the calculated measurement error (ME) at each gas 
level. For IP-CEMS, you must also record the measured concentrations 
of the native HCl before and after introduction of each reference 
gas, the path lengths of the calibration cell and the stack optical 
path, the stack and calibration cell temperatures, the stack and 
calibration cell pressures, the instrument line strength factor, and 
the calculated equivalent concentration of reference gas.
    10.1.8.1.12 For each quarterly dynamic spiking audit (DSA) of an 
HCl monitor, record the date and time of the zero gas injection and 
each spike injection, the results of the zero gas injection, the gas 
concentrations (mid and high) and the dilution factors and the 
monitor response for each of the six upscale injections as well as 
the corresponding native HCl concentrations measured before and 
after each injection. Also record the average dynamic spiking error 
for each of the upscale gases, the calculated average DSA Accuracy 
at each upscale gas concentration, and all calculations leading to 
the DSA Accuracy.
* * * * *

11. Reporting Requirements

* * * * *
    11.3.1 For an EGU that begins reporting hourly HCl and/or HF 
concentrations with a previously-certified CEMS, submit the 
monitoring plan information in section 10.1.1.2 of this appendix 
prior to or concurrent with the first required quarterly emissions 
report. For a new EGU, or for an EGU switching to continuous 
monitoring of HCl and/or HF emissions after having implemented 
another allowable compliance option under this subpart, submit the 
information in section 10.1.1.2 of this appendix at least 21 days 
prior to the start

[[Page 20366]]

of initial certification testing of the CEMS. Also submit the 
monitoring plan information in 40 CFR 75.53(g) pertaining to any 
required flow rate, diluent gas, and moisture monitoring systems 
within the applicable time frame specified in this section, if the 
required records are not already in place.
* * * * *
    11.4 Certification, Recertification, and Quality-Assurance Test 
Reporting Requirements. Except for daily QA tests (i.e., 
calibrations and flow monitor interference checks), which are 
included in each electronic quarterly emissions report, use the 
ECMPS Client Tool to submit the results of all required 
certification, recertification, quality-assurance, and diagnostic 
tests of the monitoring systems required under this appendix 
electronically. Submit the test results either prior to or 
concurrent with the relevant quarterly electronic emissions report. 
However, for RATAs of the HCl monitor, if this is not possible, you 
have up to 60 days after the test completion date to submit the test 
results; in this case, you may claim provisional status for the 
emissions data affected by the test, starting from the date and hour 
in which the test was completed and continuing until the date and 
hour in which the test results are submitted. If the test is 
successful, the status of the data in that time period changes from 
provisional to quality-assured, and no further action is required. 
However, if the test is unsuccessful, the provisional data must be 
invalidated and resubmission of the affected emission report(s) is 
required.
    11.4.1 For each daily calibration drift (or calibration error) 
assessment (including daily calibration transfer standard tests), 
and for each 7-day calibration drift test of an HCl or HF monitor, 
report:
    11.4.1.1 Facility ID information;
    11.4.1.2 The monitoring component ID;
    11.4.1.3 The instrument span and span scale;
    11.4.1.4 For each gas injection, the date and time, the 
calibration gas level (zero, mid or other), the reference gas value 
(ppm), and the monitor response (ppm);
    11.4.1.5 A flag to indicate whether dynamic spiking was used for 
the upscale value (extractive HCl monitors, only);
    11.4.1.6 Calibration drift or calibration error (percent of span 
or reference gas, as applicable);
    11.4.1.7 When using the dynamic spiking option, the measured 
concentration of native HCl before and after each mid-level spike 
and the spiked gas dilution factor; and
    11.4.1.8 When using an IP-CEMS, also report the measured 
concentration of native HCl before and after each upscale 
measurement, the path lengths of the calibration cell and the stack 
optical path, the stack and calibration cell temperatures, the stack 
and calibration cell pressures, the instrument line strength factor, 
and the equivalent concentration of the reference gas; and
    11.4.1.9 Reason for test (for the 7-day CD test, only).
    11.4.2 For each quarterly gas audit of an HCl or HF CEMS that is 
following PS 15 of appendix B to part 60 of this chapter, report:
* * * * *
    11.4.3.11 Standard deviation, using either Equation 2-4 in 
section 12.3 of Performance Specification 2 in appendix B to part 60 
of this chapter or Equation 10 in section 12.6.5 of PS 18 of 
appendix B to part 60 of this chapter;
    11.4.3.12 Confidence coefficient, using either Equation 2-5 in 
section 12.4 of Performance Specification 2 in appendix B to part 60 
of this chapter or Equation 11 in section 12.6.6 of PS 18 of 
appendix B to part 60 of this chapter;
    11.4.3.13 t-value; and
    11.4.3.14 Relative Accuracy (RA). For FTIR monitoring systems 
following PS 15 of appendix B to part 60 of this chapter, calculate 
the RA using Equation 2-6 of Performance Specification 2 in appendix 
B to part 60 of this chapter or, if applicable, according to the 
alternative procedure for low emitters described in section 3.1.2.2 
of this appendix. For HCl CEMS following PS 18 of appendix B to part 
60 of this chapter, calculate the RA according to section 12.6 of PS 
18. If applicable use a flag to indicate that the alternative RA 
specification for low emitters has been applied.
    11.4.4 For each 3-level measurement error test of an HCl 
monitor, report:
    11.4.4.1 Facility ID information;
    11.4.4.2 Monitoring component ID;
    11.4.4.3 Instrument span and span scale;
    11.4.4.4 For each gas injection, the date and time, the 
calibration gas level (low, mid, or high), the reference gas value 
in ppm and the monitor response. When using an IP-CEMS, also report 
the measured concentration of native HCl before and after each 
injection, the path lengths of the calibration cell and the stack 
optical path, the stack and calibration cell temperatures, the stack 
and calibration cell pressures, the instrument line strength factor, 
and the equivalent concentration of the reference gas;
    11.4.4.5 For extractive CEMS, the mean reference value and mean 
of measured values at each reference gas level (ppm). For IP-CEMS, 
the mean of the measured concentration minus the average measured 
native concentration minus the equivalent reference gas 
concentration (ppm), at each reference gas level--see Equation 6A in 
PS 18 of appendix B to part 60 of this chapter;
    11.4.4.6 Measurement error (ME) at each reference gas level; and
    11.4.4.7 Reason for test.
    11.4.5 Beam intensity tests of an IP CEMS:
    11.4.5.1 For the initial beam intensity test described in 
Performance Specification 18 in appendix B to part 60 of this 
chapter, report:
    11.4.5.1.1 Facility ID information;
    11.4.5.1.2 Date and time of the test;
    11.4.5.1.3 Monitoring system ID;
    11.4.5.1.4 Reason for test;
    11.4.5.1.5 Attenuation value (%);
    11.4.5.1.6 High level gas concentration (ppm);
    11.4.5.1.7 Full and attenuated beam intensity levels, including 
units of measure;
    11.4.5.1.8 Measured HCl concentrations at full and attenuated 
beam intensity (ppm); and
    11.4.5.1.9 Percentage difference between the HCl concentrations.
    11.4.5.2 For the daily beam intensity check described in 
Procedure 6 of appendix F to part 60 of this chapter, report:
    11.4.5.2.1 Facility ID information;
    11.4.5.2.2 Date and time of the test;
    11.4.5.2.3 Monitoring system ID;
    11.4.5.2.4 The attenuated beam intensity level (limit) 
established in the initial test;
    11.4.5.2.5 The beam intensity measured during the daily check; 
and
    11.4.5.2.6 Results of the test (pass or fail).
    11.4.6 For each temperature or pressure verification or audit of 
an HCl IP-CEMS, report:
    11.4.6.1 Facility ID information;
    11.4.6.2 Date and time of the test;
    11.4.6.3 Monitoring system ID;
    11.4.6.4 Type of verification (T or P);
    11.4.6.5 Stack sensor measured value;
    11.4.6.6 Reference device measured value;
    11.4.6.7 Results of the test (pass or fail); and
    11.4.6.8 Reason for test.
    11.4.7 For each interference test of an HCl monitoring system, 
report:
    11.4.7.1 Facility ID information;
    11.4.7.2 Date of test;
    11.4.7.3 Monitoring system ID;
    11.4.7.4 Results of the test (pass or fail);
    11.4.7.5 Reason for test; and
    11.4.7.6 A flag to indicate whether the test was performed: on 
this particular monitoring system; on one of multiple systems of the 
same type; or by the manufacturer on a system with components of the 
same make and model(s) as this system.
    11.4.8 For each level of detection (LOD) test of an HCl monitor, 
report:
    11.4.8.1 Facility ID information;
    11.4.8.2 Date of test;
    11.4.8.3 Reason for test;
    11.4.8.4 Monitoring system ID;
    11.4.8.5 A code to indicate whether the test was done in a 
controlled environment or in the field;
    11.4.8.6 HCl reference gas concentration;
    11.4.8.7 HCl responses with interference gas (7 repetitions);
    11.4.8.8 Standard deviation of HCl responses;
    11.4.8.9 Effective spike addition gas concentrations;
    11.4.8.10 HCl concentration measured without spike;
    11.4.8.11 HCl concentration measured with spike;
    11.4.8.12 Dilution factor for spike;
    11.4.8.13 The controlled environment LOD value (ppm or ppm-
meters);
    11.4.8.14 The field determined standard addition detection level 
(SADL in ppm or ppm-meters); and
    11.4.8.15 Result of LDO/SADL test (pass/fail).
    11.4.9 For each ME or LOD response time test of an HCl monitor, 
report:
    11.4.9.1 Facility ID information;
    11.4.9.2 Date of test;
    11.4.9.3 Monitoring component ID;
    11.4.9.4 The higher of the upscale or downscale tests, in 
minutes; and
    11.4.9.5 Reason for test.
    11.4.10 For each quarterly relative accuracy audit of an HCl 
monitor, report:

[[Page 20367]]

    11.4.10.1 Facility ID information;
    11.4.10.2 Monitoring system ID;
    11.4.10.3 Begin and end time of each test run;
    11.4.10.4 The reference method used;
    11.4.10.5 The reference method (RM) and CEMS values for each 
test run, including the units of measure;
    11.4.10.6 The mean RM and CEMS values for the three test runs;
    11.4.10.7 The calculated relative accuracy (RA), percent; and
    11.4.10.8 Reason for test.
    11.4.11 For each quarterly cylinder gas audit of an HCl monitor, 
report:
    11.4.11.1 Facility ID information;
    11.4.11.2 Monitoring component ID;
    11.4.11.3 Instrument span and span scale;
    11.4.11.4 For each gas injection, the date and time, the 
reference gas level (zero, mid, or high), the reference gas value in 
ppm, and the monitor response. When using an IP-CEMS, also report 
the measured concentration of native HCl before and after each 
injection, the path lengths of the calibration cell and the stack 
optical path, the stack and calibration cell temperatures, the stack 
and calibration cell pressures, the instrument line strength factor, 
and the equivalent concentration of the reference gas;
    11.4.11.5 For extractive CEMS, the mean reference gas value and 
mean monitor response at each reference gas level (ppm). For IP-
CEMS, the mean of the measured concentration minus the average 
measured native concentration minus the equivalent reference gas 
concentration (ppm), at each reference gas level--see Equation 6A in 
PS 18 of appendix B to part 60 of this chapter;
    11.4.11.6 Measurement error (ME) at each reference gas level; 
and
    11.4.11.7 Reason for test.
    11.4.12 For each quarterly dynamic spiking audit of an HCl 
monitor, report:
    11.4.12.1 Facility ID information;
    11.4.12.2 Monitoring component ID;
    11.4.12.3 Instrument span and span scale;
    11.4.12.4 For the zero gas injection, the date and time, and the 
monitor response (Note: The zero gas injection from a calibration 
drift check performed on the same day as the upscale spikes may be 
used for this purpose.);
    11.4.12.5 Zero spike error;
    11.4.12.6 For the upscale gas spiking, the date and time of each 
spike, the reference gas level (mid- or high-), the reference gas 
value (ppm), the dilution factor, the native HCl concentrations 
before and after each spike, and the monitor response for each gas 
spike;
    11.4.12.7 Upscale spike error;
    11.4.12.8 Dynamic spike accuracy (DSA) at the zero level and at 
each upscale gas level; and
    11.4.12.9 Reason for test.
    11.4.13 Reporting Requirements for Diluent Gas, Flow Rate, and 
Moisture Monitoring Systems. For the certification, recertification, 
diagnostic, and QA tests of stack gas flow rate, moisture, and 
diluent gas monitoring systems that are certified and quality-
assured according to part 75 of this chapter, report the information 
in section 10.1.8.2 of this appendix.
* * * * *
    11.5.1 The owner or operator of any affected unit shall use the 
ECMPS Client Tool to submit electronic quarterly reports to the 
Administrator in an XML format specified by the Administrator, for 
each affected unit (or group of units monitored at a common stack). 
If the certified HCl or HF CEMS is used for the initial compliance 
demonstration, HCl or HF emissions reporting shall begin with the 
first operating hour of the 30 boiler operating day compliance 
demonstration period. Otherwise, HCl or HF emissions reporting shall 
begin with the first operating hour after successfully completing 
all required certification tests of the CEMS.
* * * * *
0
17. Add appendix C to subpart UUUUU to read as follows:

Appendix C to Subpart UUUUU of Part 63--PM Monitoring Provisions

1. General Provisions

    1.1 Applicability. These monitoring provisions apply to the 
continuous measurement of filterable particulate matter (PM) 
emissions from affected EGUs under this subpart. A particulate 
matter continuous emission monitoring system (PM CEMS) is used 
together with other continuous monitoring systems and (as 
applicable) parametric measurement devices to quantify PM emissions 
in units of the applicable standard (i.e., lb/MMBtu or lb/MWh).
    1.2 Initial Certification and Recertification Procedures. You, 
as the owner or operator of an affected EGU that uses a PM CEMS to 
demonstrate compliance with a filterable PM emissions limit in Table 
1 or 2 to this subpart must certify and, if applicable, recertify 
the CEMS according to Performance Specification 11 (PS-11) in 
appendix B to part 60 of this chapter.
    1.3 Quality Assurance and Quality Control Requirements. You must 
meet the applicable quality assurance requirements of Procedure 2 in 
appendix F to part 60 of this chapter.
    1.4 Missing Data Procedures. You must not substitute data for 
missing data from the PM CEMS. Any process operating hour for which 
quality-assured PM concentration data are not obtained is counted as 
an hour of monitoring system downtime.
    1.5 Adjustments for Flow System Bias. When the PM emission rate 
is reported on a gross output basis, you must not adjust the data 
recorded by a stack gas flow rate monitor for bias, which may 
otherwise be required under 40 CFR 75.24.

2. Monitoring of PM Emissions

    2.1 Monitoring System Installation Requirements. Flue gases from 
the affected EGUs under this subpart vent to the atmosphere through 
a variety of exhaust configurations including single stacks, common 
stack configurations, and multiple stack configurations. For each of 
these configurations, Sec.  63.10010(a) specifies the appropriate 
location(s) at which to install continuous monitoring systems (CMS). 
These CMS installation provisions apply to the PM CEMS and to the 
other continuous monitoring systems and parametric monitoring 
devices that provide data for the PM emissions calculations in 
section 6 of this appendix.
    2.2 Primary and Backup Monitoring Systems. In the electronic 
monitoring plan described in section 7 of this appendix, you must 
create and designate a primary monitoring system for PM and for each 
additional parameter (i.e., stack gas flow rate, CO2 or 
O2 concentration, stack gas moisture content, as 
applicable). The primary system must be used to report hourly PM 
concentration values when the system is able to provide quality-
assured data, i.e., when the system is ``in control.'' However, to 
increase data availability in the event of a primary monitoring 
system outage, you may install, operate, maintain, and calibrate a 
redundant backup monitoring system. A redundant backup system is one 
that is permanently installed at the unit or stack location and is 
kept on ``hot standby'' in case the primary monitoring system is 
unable to provide quality-assured data. You must represent each 
redundant backup system as a unique monitoring system in the 
electronic monitoring plan. You must certify each redundant backup 
monitoring system according to the applicable provisions in section 
4 of this appendix. In addition, each redundant monitoring system 
must meet the applicable on-going QA requirements in section 5 of 
this appendix.

3. PM Emissions Measurement Methods

    The following definitions, equipment specifications, procedures, 
and performance criteria are applicable
    3.1 Definitions. All definitions specified in section 3 of PS-11 
in appendix B to part 60 of this chapter and section 3 of Procedure 
2 in appendix F to part 60 of this chapter are applicable to the 
measurement of filterable PM emissions from electric utility steam 
generating units under this subpart. In addition, the following 
definitions apply:
    3.1.1 Stack operating hour means a clock hour during which flue 
gases flow through a particular stack or duct (either for the entire 
hour or for part of the hour) while the associated unit(s) are 
combusting fuel.
    3.1.2 Unit operating hour means a clock hour during which a unit 
combusts any fuel, either for part of the hour or for the entire 
hour.
    3.2 Continuous Monitoring Methods.
    3.2.1 Installation and Measurement Location. You must install 
the PM CEMS according to Sec.  63.10010 and Section 2.4 of PS-11 in 
appendix B to part 60 of this chapter.
    3.2.2 Units of Measure. For the purposes of this subpart, you 
shall report hourly PM concentrations in units of measure that 
correspond to your PM CEMS correlation curve (e.g., mg/acm, mg/acm 
@160 [deg]C, mg/wscm, mg/dscm).
    3.2.3 Other Necessary Data Collection. To convert hourly PM 
concentrations to the units of the applicable emissions standard 
(i.e., lb/MMBtu or lb/MWh), you must collect additional data as 
described in sections 3.2.3.1 and 3.2.3.2 of this appendix. You must 
install, certify, operate, maintain, and quality-assure any stack 
gas flow rate, CO2, O2, or moisture monitoring 
systems needed for this purpose according to sections 4 and 5 of 
this appendix. The calculation methods for the emission limits 
described in sections

[[Page 20368]]

3.2.3.1 and 3.2.3.2 of this appendix are presented in section 6 of 
this appendix.
    3.2.3.1 Heat Input-Based Emission Limits. To demonstrate 
compliance with a heat input-based PM emission limit in Table 2 to 
this subpart, you must provide the hourly stack gas CO2 
or O2 concentration, along with a fuel-specific 
Fc factor or dry-basis F-factor and (if applicable) the 
stack gas moisture content, in order to convert measured PM 
concentrations values to the units of the standard.
    3.2.3.2 Gross Output-Based Emission Limits. To demonstrate 
compliance with a gross output-based PM emission limit in Table 1 or 
2 to this subpart, you must provide the hourly gross output in 
megawatts, along with data from a certified stack gas flow rate 
monitor and (if applicable) the stack gas moisture content, in order 
to convert measured PM concentrations values to units of the 
standard.

4. Certification and Recertification Requirements

    4.1 Certification Requirements. You must certify your PM CEMS 
and the other continuous monitoring systems used to determine 
compliance with the applicable emissions standard before the PM CEMS 
can be used to provide data under this subpart. Redundant backup 
monitoring systems (if used) are subject to the same certification 
requirements as the primary systems.
    4.1.1 PM CEMS. You must certify your PM CEMS according to PS-11 
in appendix B to part 60 of this chapter. A PM CEMS that has been 
installed and certified according to PS-11 as a result of another 
state or Federal regulatory requirement or consent decree prior to 
[EFFECTIVE DATE OF THE FINAL RULE] shall be considered certified for 
this subpart if you can demonstrate that your PM CEMS meets the PS-
11 acceptance criteria based on the applicable emission standard in 
this subpart.
    4.1.2 Flow Rate, Diluent Gas, and Moisture Monitoring Systems. 
You must certify the continuous monitoring systems that are needed 
to convert PM concentrations to units of the standard or (if 
applicable) to convert the measured PM concentrations from wet basis 
to dry basis or vice-versa (i.e., stack gas flow rate, diluent gas 
(CO2 or O2) concentration, or moisture 
monitoring systems), in accordance with the applicable provisions in 
40 CFR 75.20 and appendix A to part 75 of this chapter.
    4.1.3 Other Parametric Measurement Devices. Any temperature or 
pressure measurement devices that are used to convert hourly PM 
concentrations to standard conditions must be installed, calibrated, 
maintained, and operated according to the manufacturers' 
instructions.
    4.2 Recertification.
    4.2.1 You must recertify your PM CEMS if it is either: Moved to 
a different stack or duct; moved to a new location within the same 
stack or duct; modified or repaired in such a way that the existing 
correlation is altered or impacted; or replaced.
    4.2.2 The flow rate, diluent gas, and moisture monitoring 
systems that are used to convert PM concentration to units of the 
emission standard are subject to the recertification provisions in 
40 CFR 75.20(b).
    4.3 Development of a New or Revised Correlation Curve. You must 
develop a new or revised correlation curve if:
    4.3.1 A response correlation audit (RCA) is failed and the new 
or revised correlation is developed according to section 10.6 in 
Procedure 2 of appendix F to part 60 of this chapter; or
    4.3.2 The events described in paragraph (1) or (2) in section 
8.8 of PS-11 in appendix B to part 60 of this chapter occur.

5. Ongoing Quality Assurance (QA) and Data Validation

    5.1 PM CEMS.
    5.1.1 Required QA Tests. Following initial certification, you 
must conduct periodic QA testing of each primary and (if applicable) 
redundant backup PM CEMS. The required QA tests and the performance 
specifications that must be met are found in Procedure 2 of appendix 
F to part 60 of this chapter (Procedure 2). Except as otherwise 
provided in section 5.1.2 of this appendix, the QA tests shall be 
done at the frequency specified in Procedure 2.
    5.1.2 RRA and RCA Test Frequencies.
    5.1.2.1 The test frequency for RRAs of the PM CEMS shall be 
annual, i.e., once every four calendar quarters. The RRA must either 
be performed within the fourth calendar quarter after the calendar 
quarter in which the previous RRA was completed or in a grace period 
(see section 5.1.3 of this appendix). When a required annual RRA is 
done within a grace period, the deadline for the next RRA is four 
calendar quarters after the quarter in which the RRA was originally 
due, rather than the calendar quarter in which the grace period test 
is completed.
    5.1.2.2 The test frequency for RCAs of the PM CEMS shall be 
triennial, i.e., once every twelve calendar quarters. If a required 
RCA is not completed within twelve calendar quarters after the 
calendar quarter in which the previous RCA was completed, it must be 
performed in a grace period immediately following the twelfth 
calendar quarter (see section 5.1.3 of this appendix). When an RCA 
is done in a grace period, the deadline for the next RCA shall be 
twelve calendar quarters after the calendar quarter in which the RCA 
was originally due, rather than the calendar quarter in which the 
grace period test is completed.
    5.1.2.3 Successive quarterly audits (i.e., ACAs and, if 
applicable, sample volume audits (SVAs)) shall be conducted at least 
60 days apart.
    5.1.3 Grace Period. A grace period is available, immediately 
following the end of the calendar quarter in which an RRA or RCA of 
the PM CEMS is due. The length of the grace period shall be the 
lesser of 720 EGU (or stack) operating hours or one calendar 
quarter.
    5.1.4 RCA and RRA Acceptability. The results of your RRA or RCA 
are considered acceptable provided that the criteria in section 
10.4(5) of Procedure 2 in appendix F to part 60 of this chapter are 
met for an RCA or section 10.4(6) of Procedure 2 in appendix F to 
part 60 of this chapter are met for an RRA.
    5.1.5 Data Validation. Your PM CEMS is considered to be out-of-
control, and you may not report data from it as quality-assured, 
when, for a required certification, recertification, or QA test, the 
applicable acceptance criterion (either in PS-11 in appendix B to 
part 60 of this chapter or Procedure 2 in appendix F to part 60 of 
this chapter) is not met. Further, data from your PM CEMS are 
considered out-of-control, and may not be used for reporting, when a 
required QA test is not performed on schedule or within an allotted 
grace period. When an out-of-control period occurs, you must perform 
the appropriate follow-up actions. For an out-of-control period 
triggered by a failed QA test, you must perform and pass the same 
type of test in order to end the out-of-control period. For a QA 
test that is not performed on time, data from the PM CEMS remain 
out-of-control until the required test has been performed and 
passed. You must count all out-of-control data periods of the PM 
CEMS as hours of monitoring system downtime.
    5.2 Stack Gas Flow Rate, Diluent Gas, and Moisture Monitoring 
Systems. The on-going QA test requirements and data validation 
criteria for the primary and (if applicable) redundant backup stack 
gas flow rate, diluent gas, and moisture monitoring systems are 
specified in appendix B to part 75 of this chapter.
    5.3 QA/QC Program Requirements. You must develop and implement a 
quality assurance/quality control (QA/QC) program for the PM CEMS 
and the other equipment that is used to provide data under this 
subpart. You may store your QA/QC plan electronically, provided that 
the information can be made available expeditiously in hard copy to 
auditors and inspectors.
    5.3.1 General Requirements.
    5.3.1.1 Preventive Maintenance. You must keep a written record 
of the procedures needed to maintain the PM CEMS and other equipment 
that is used to provide data under this subpart in proper operating 
condition, along with a schedule for those procedures. At a minimum, 
you must include all procedures specified by the manufacturers of 
the equipment and, if applicable, additional or alternate procedures 
developed for the equipment.
    5.3.1.2 Recordkeeping Requirements. You must keep a written 
record describing procedures that will be used to implement the 
recordkeeping and reporting requirements of this appendix.
    5.3.1.3 Maintenance Records. You must keep a record of all 
testing, maintenance, or repair activities performed on the PM CEMS, 
and other equipment used to provide data under this subpart in a 
location and format suitable for inspection. You may use a 
maintenance log for this purpose. You must maintain the following 
records for each system or device: The date, time, and description 
of any testing, adjustment, repair, replacement, or preventive 
maintenance action performed, and records of any corrective actions 
taken. Additionally, you must record any adjustment that may affect 
the ability of a monitoring system or measurement device to make 
accurate measurements, and you must keep a written explanation of 
the procedures used to make the adjustment(s).
    5.3.2 Specific Requirements for the PM CEMS.

[[Page 20369]]

    5.3.2.1 Daily, and Quarterly QA Assessments. You must keep a 
written record of the procedures used for daily assessments of the 
PM CEMS. You must also keep records of the procedures used to 
perform quarterly ACA and (if applicable) SVA audits. You must 
document how the test results are calculated and evaluated.
    5.3.2.2 Monitoring System Adjustments. You must document how 
each component of the PM CEMS will be adjusted to provide correct 
responses after routine maintenance, repairs, or corrective actions.
    5.3.2.3 Correlation Tests, Annual and Triennial Audits. You must 
keep a written record of procedures used for the correlation 
test(s), annual RRAs, and triennial RCAs of the PM CEMS. You must 
document how the test results are calculated and evaluated.
    5.3.3 Specific Requirements for Diluent Gas, Stack Gas Flow 
Rate, and Moisture Monitoring Systems. The QA/QC program 
requirements for the stack gas flow rate, diluent gas, and moisture 
monitoring systems described in section 3.2.3 of this appendix are 
specified in section 1 of appendix B to part 75 of this chapter.
    5.3.4 Requirements for Other Monitoring Equipment. For the 
equipment required to convert readings from the PM CEMS to standard 
conditions (e.g., devices to measure temperature and pressure), you 
must keep a written record of the calibrations and/or other 
procedures used to ensure that the devices provide accurate data.
    5.3.5 You may store your QA/QC plan electronically, provided 
that you can make the information available expeditiously in hard 
copy to auditors or inspectors.

6. Data Reduction and Calculations

    6.1 Data Reduction and Validation.
    6.1.1 You must reduce the data from PM CEMS to hourly averages, 
in accordance with 40 CFR 60.13(h)(2).
    6.1.2 You must reduce all CEMS data from stack gas flow rate, 
CO2, O2, and moisture monitoring systems to 
hourly averages according to 40 CFR 75.10(d)(1).
    6.1.3 You must reduce all other data from devices used to 
convert readings from the PM CEMS to standard conditions to hourly 
averages according to 40 CFR 60.13(h)(2) or 75.10(d)(1). This 
includes, but is not limited to, data from devices used to measure 
temperature and pressure, or, for cogeneration units that calculate 
gross output based on steam characteristics, devices to measure 
steam flow rate, steam pressure, and steam temperature.
    6.1.4 Do not calculate the PM emission rate for any unit or 
stack operating hour in which valid data are not obtained for PM 
concentration or for any parameter used in the PM emission rate 
calculations (i.e., gross output, stack gas flow rate, stack 
temperature, stack pressure, stack gas moisture content, or diluent 
gas concentration, as applicable).
    6.1.5 For the purposes of this appendix, part 75 substitute data 
values for stack gas flow rate, CO2 concentration, 
O2 concentration, and moisture content are not considered 
to be valid data.
    6.1.6 Operating hours in which PM concentration is missing or 
invalid are hours of monitoring system downtime. The use of 
substitute data for PM concentration is not allowed.
    6.1.7 You must exclude all data obtained during a boiler startup 
or shutdown operating hour (as defined in Sec.  63.10042) from the 
determination of the 30-boiler operating day rolling average PM 
emission rates.
    6.2 Calculation of PM Emission Rates. Unless your PM CEMS is 
correlated to provide PM concentrations at standard conditions, you 
must use the calculation methods in sections 6.2.1 through 6.2.3 of 
this appendix to convert measured PM concentration values to units 
of the emission limit (lb/MMBtu or lb/MWh, as applicable).
    6.2.1 p.m. concentrations must be at standard conditions in 
order to convert them to units of the emissions limit. If your PM 
CEMS measures PM concentrations at standard conditions, proceed to 
section 6.2.2 or 6.2.3 of this appendix (as applicable). However, if 
your PM CEMS measures PM concentrations in units of mg/acm or mg/acm 
at a specified temperature (e.g., 160 [deg]C), you must first use 
one of the following equations to convert the hourly PM 
concentration values from actual to standard conditions:
[GRAPHIC] [TIFF OMITTED] TP10AP20.003

Where:

Cstd = PM concentration at standard conditions.
Ca = PM concentration at measurement conditions.
Ts = Stack Temperature ([deg]F).
TCEMS = CEMS Measurement Temperature ([deg]F).
PCEMS = CEMS Measurement Pressure (in. Hg).
Ps = Stack Pressure (in. Hg).
Tstd = Standard Temperature (68 [deg]F).
Pstd = Standard Pressure (29.92 in. Hg).

    6.2.2 Heat Input-Based PM Emission Rates (Existing EGUs, Only). 
Calculate the hourly heat input-based PM emission rates (if 
applicable), in units of lb/MMBtu, according to sections 6.2.2.1 and 
6.2.2.2 of this appendix.
    6.2.2.1 You must select an appropriate emission rate equation 
from among Equations 19-1 through 19-9 in test Method 19 in appendix 
A-7 to part 60 of this chapter to convert the hourly PM 
concentration values from section 6.2.1 of this appendix to units of 
lb/MMBtu. Note that the EPA test Method 19 equations require the 
pollutant concentration to be expressed in units of lb/scf; 
therefore, you must first multiply the PM concentration by 6.24 x 
10-8 to convert it from mg/scm to lb/scf.
    6.2.2.2 You must use the appropriate carbon-based or dry-basis 
F-factor in the emission rate equation that you have selected. You 
may either use an F-factor from Table 19-2 of EPA test Method 19 in 
appendix A-7 to part 60 of this chapter or from section 3.3.5 or 
3.3.6 of appendix F to part 75 of this chapter.
    6.2.2.3 If the hourly average O2 concentration is 
above 14.0% O2 (19.0% for an IGCC) or the hourly average 
CO2 concentration is below 5.0% CO2 (1.0% for 
an IGCC), you may calculate the PM emission rate using the 
applicable diluent cap value (as defined in Sec.  63.10042 and 
specified in Sec.  63.10007(f)(1)), provided that the diluent gas 
monitor is operating and recording quality-assured data).
    6.2.2.4 If your selected EPA test Method 19 equation requires a 
correction for the stack gas moisture content, you may either use 
quality-assured hourly data from a certified part 75 moisture 
monitoring system, a fuel-specific default moisture value from 40 
CFR 75.11(b), or a site-specific default moisture value approved by 
the Administrator under 40 CFR 75.66.
    6.2.3 Gross Output-Based PM Emission Rates. For each unit or 
stack operating hour, if Cstd is measured on a wet basis, 
you must use Equation C-3 of this section to calculate the gross 
output-based PM emission rate (if applicable). Use Equation C-4 of 
this section if Cstd is measured on a dry basis:

[[Page 20370]]

[GRAPHIC] [TIFF OMITTED] TP10AP20.004

Where:

Eheo = Hourly gross output-based PM emission rate (lb/
MWh).
Cstd = PM concentration from section 6.2.1 (mg/scm), wet 
basis.
Qs = Unadjusted stack gas volumetric flow rate (scfh, wet 
basis).
MW = Gross output (megawatts).
6.24 x 10-8 = Conversion factor.

[GRAPHIC] [TIFF OMITTED] TP10AP20.005

Where:

Eheo = Hourly gross output-based PM emission rate (lb/
MWh).
Cstd = PM concentration from section 6.2.1 (mg/scm), dry 
basis.
Qs = Unadjusted stack gas volumetric flow rate (scfh, wet 
basis).
MW = Gross output (megawatts).
Bws = Proportion by volume of water vapor in the stack 
gas.
6.24 x 10-8 = Conversion factor.

6.2.4 You must calculate the 30-boiler operating day rolling average 
PM emission rates according to Sec.  63.10021(b).

7. Recordkeeping and Reporting

    7.1 Recordkeeping Provisions. For the PM CEMS and the other 
necessary continuous monitoring systems (CMS) and parameter 
measurement devices installed at each affected unit or common stack, 
you must maintain a file of all measurements, data, reports, and 
other information required by this appendix in a form suitable for 
inspection, for 5 years from the date of each record, in accordance 
with Sec.  63.10033. The file shall contain the applicable 
information in sections 7.1.1 through 7.1.11 of this appendix.
    7.1.1 Monitoring Plan Records. For each EGU or group of EGUs 
monitored at a common stack, you must prepare and maintain a 
monitoring plan for the PM CEMS and the other CMS(s) needed to 
convert PM concentrations to units of the applicable emission 
standard.
    7.1.1.1 Updates. If you make a replacement, modification, or 
change in a certified CEMS that is used to provide data under this 
appendix (including a change in the automated data acquisition and 
handling system) or if you make a change to the flue gas handling 
system and that replacement, modification, or change affects 
information reported in the monitoring plan (e.g., a change to a 
serial number for a component of a monitoring system), you shall 
update the monitoring plan.
    7.1.1.2 Contents of the Monitoring Plan. For the PM CEMS, your 
monitoring plan shall contain the applicable information in sections 
7.1.1.2.1 and 7.1.1.2.2 of this appendix. For required stack gas 
flow rate, diluent gas, and moisture monitoring systems, your 
monitoring plan shall include the applicable information required 
for those systems under 40 CFR 75.53(g) and (h).
    7.1.1.2.1 Electronic. Your electronic monitoring plan records 
must include the following information: Unit or stack ID number(s); 
unit information (type of unit, maximum rated heat input, fuel 
type(s), emission controls); monitoring location(s); the monitoring 
methodologies used; monitoring system information, including (as 
applicable): Unique system and component ID numbers; the make, 
model, and serial number of the monitoring equipment; the sample 
acquisition method; formulas used to calculate emissions; operating 
range and load information; monitor span and range information; 
units of measure of your PM concentrations (see section 3.2.2 of 
this appendix); and appropriate default values. Your electronic 
monitoring plan shall be evaluated and submitted using the Emissions 
Collection and Monitoring Plan System (ECMPS) Client Tool provided 
by the Clean Air Markets Division (CAMD) in EPA's Office of 
Atmospheric Programs.
    7.1.1.2.2 Hard Copy. You must keep records of the following 
items: Schematics and/or blueprints showing the location of the PM 
monitoring system(s) and test ports; data flow diagrams; test 
protocols; and miscellaneous technical justifications. The hard copy 
portion of the monitoring plan must also explain how the PM 
concentrations are measured and how they are converted to the units 
of the applicable emissions limit. The equation(s) used for the 
conversions must be documented. Electronic storage of the hard copy 
portion of the monitoring plan is permitted.
    7.1.2 Operating Parameter Records. You must record the following 
information for each operating hour of each EGU and also for each 
group of EGUs utilizing a monitored common stack, to the extent that 
these data are needed to convert PM concentration data to the units 
of the emission standard. For non-operating hours, you must record 
only the items in sections 7.1.2.1 and 7.1.2.2 of this appendix. If 
you elect to or are required to comply with a gross output-based PM 
standard, for any hour in which there is gross output greater than 
zero, you must record the items in sections 7.1.2.1 through 7.1.2.3 
and (if applicable) 7.1.2.5 of this appendix; however, if there is 
heat input to the unit(s) but no gross output (e.g., at unit 
startup), you must record the items in sections 7.1.2.1, 7.1.2.2, 
and, if applicable, section 7.1.2.5 of this appendix. If you elect 
to comply with a heat input-based PM standard, you must record only 
the items in sections 7.1.2.1, 7.1.2.2, 7.1.2.4, and, if applicable, 
section 7.1.2.5 of this appendix.
    7.1.2.1 The date and hour;
    7.1.2.2 The unit or stack operating time (rounded up to the 
nearest fraction of an hour (in equal increments that can range from 
one hundredth to one quarter of an hour, at your option);
    7.1.2.3 The hourly gross output (rounded to nearest MWe);
    7.1.2.4 If applicable, the Fc factor or dry-basis F-
factor used to calculate the heat input-based PM emission rate; and
    7.1.2.5 If applicable, a flag to indicate that the hour is an 
exempt startup or shutdown hour.
    7.1.3 PM Concentration Records. For each affected unit or common 
stack using a PM CEMS, you must record the following information for 
each unit or stack operating hour:
    7.1.3.1 The date and hour;
    7.1.3.2 Monitoring system and component identification codes for 
the PM CEMS, as provided in the electronic monitoring plan, if your 
CEMS provides a quality-assured value of PM concentration for the 
hour;
    7.1.3.3 The hourly PM concentration, in units of measure that 
correspond to your PM CEMS correlation curve, for each operating 
hour in which a quality-assured value is obtained. Record all PM 
concentrations with one leading non-zero digit and one decimal 
place, expressed in scientific notation. Use the following rounding 
convention: if the digit immediately following the first decimal 
place is 5 or greater, round the first decimal place upward 
(increase it by one); if the digit immediately following the first 
decimal place is 4 or less, leave the first decimal place unchanged.
    7.1.3.4 A special code, indicating whether or not a quality-
assured PM concentration is obtained for the hour; and
    7.1.3.5 Monitor data availability for PM concentration, as a 
percentage of unit or stack operating hours calculated in the manner 
established for SO2, CO2, O2 or 
moisture monitoring systems according to 40 CFR 75.32.
    7.1.4 Stack Gas Volumetric Flow Rate Records.

[[Page 20371]]

    7.1.4.1 When a gross output-based PM emissions limit must be 
met, in units of lb/MWh, you must obtain hourly measurements of 
stack gas volumetric flow rate during EGU operation, in order to 
convert PM concentrations to units of the standard.
    7.1.4.2 When hourly measurements of stack gas flow rate are 
needed, you must keep hourly records of the flow rates and related 
information, as specified in 40 CFR 75.57(c)(2).
    7.1.5 Records of Diluent Gas (CO2 or O2) 
Concentration.
    7.1.5.1 When a heat input-based PM emission limit must be met, 
in units of lb/MMBtu, you must obtain hourly measurements of 
CO2 or O2 concentration during EGU operation, 
in order to convert PM concentrations to units of the standard.
    7.1.5.2 When hourly measurements of diluent gas concentration 
are needed, you must keep hourly CO2 or O2 
concentration records, as specified in 40 CFR 75.57(g).
    7.1.6 Records of Stack Gas Moisture Content.
    7.1.6.1 When corrections for stack gas moisture content are 
needed to demonstrate compliance with the applicable PM emissions 
limit:
    7.1.6.1.1 If you use a continuous moisture monitoring system, 
you must keep hourly records of the stack gas moisture content and 
related information, as specified in 40 CFR 75.57(c)(3).
    7.1.6.1.2 If you use a fuel-specific default moisture value, you 
must represent it in the electronic monitoring plan required under 
section 7.1.1.2.1 of this appendix.
    7.1.7 PM Emission Rate Records. For applicable PM emission 
limits in units of lb/MMBtu or lb/MWh, you must record the following 
information for each affected EGU or common stack:
    7.1.7.1 The date and hour;
    7.1.7.2 The hourly PM emissions rate (lb/MMBtu or lb/MWh, as 
applicable), calculated according to section 6.2.2 or 6.2.3 of this 
appendix, rounded to the same precision as the standard (i.e., with 
one leading non-zero digit and one decimal place, expressed in 
scientific notation), expressed in scientific notation. Use the 
following rounding convention: if the digit immediately following 
the first decimal place is 5 or greater, round the first decimal 
place upward (increase it by one); if the digit immediately 
following the first decimal place is 4 or less, leave the first 
decimal place unchanged. You must calculate the PM emission rate 
only when valid values of PM concentration and all other required 
parameters required to convert PM concentration to the units of the 
standard are obtained for the hour;
    7.1.7.3 An identification code for the formula used to derive 
the hourly PM emission rate from measurements of the PM 
concentration and other necessary parameters (i.e., Equation C-3 or 
C-4 in section 6.2.3 of this appendix or the applicable EPA test 
Method 19 equation);
    7.1.7.4 If applicable, indicate that the diluent cap has been 
used to calculate the PM emission rate; and
    7.1.7.5 If applicable, indicate that the default electrical load 
(as defined in Sec.  63.10042) has been used to calculate the hourly 
PM emission rate.
    7.1.7.6 Indicate that the PM emission rate was not calculated 
for the hour, if valid data are not obtained for PM concentration 
and/or any of the other parameters in the PM emission rate equation. 
For the purposes of this appendix, substitute data values for stack 
gas flow rate, CO2 concentration, O2 
concentration, and moisture content reported under part 75 of this 
chapter are not considered to be valid data. However, when the gross 
output (as defined in Sec.  63.10042) is reported for an operating 
hour with zero output, the default electrical load value is treated 
as quality-assured data.
    7.1.8 Other Parametric Data. If your PM CEMS measures PM 
concentrations at actual conditions, you must keep records of the 
temperatures and pressures used in Equation C-1 or C-2 in section 
6.2.1 of this appendix to convert the measured hourly PM 
concentrations to standard conditions.
    7.1.9 Certification, Recertification, and Quality Assurance Test 
Records. For any PM CEMS used to provide data under this subpart, 
you must record the following certification, recertification, and 
quality-assurance information:
    7.1.9.1 The test dates and times, reference values, monitor 
responses, monitor full scale value, and calculated results for the 
required 7-day drift tests and for the required daily zero and 
upscale calibration drift tests;
    7.1.9.2 The test dates and times and results (pass or fail) of 
all daily system optics checks and daily sample volume checks of the 
PM CEMS (as applicable);
    7.1.9.3 The test dates and times, reference values, monitor 
responses, and calculated results for all required quarterly ACAs;
    7.1.9.4 The test dates and times, reference values, monitor 
responses, and calculated results for all required quarterly SVAs of 
extractive PM CEMS;
    7.1.9.5 The test dates and times, reference method readings and 
corresponding PM CEMS responses (including the units of measure), 
and the calculated results for all PM CEMS correlation tests, RRAs 
and RCAs. For the correlation tests, you must indicate which model 
is used (i.e., linear, logarithmic, exponential, polynomial, or 
power) and record the correlation equation. For the RRAs and RCAs, 
the reference method readings and PM CEMS responses must be reported 
in the same units of measure as the PM CEMS correlation;
    7.1.9.6 The cycle time and sample delay time for PM CEMS that 
operate in batch sampling mode; and
    7.1.9.7 Supporting information for all required PM CEMS 
correlation tests, RRAs, and RCAs, including records of all raw 
reference method and monitoring system data, the results of sample 
analyses to substantiate the reported test results, as well as 
records of sampling equipment calibrations, reference monitor 
calibrations, and analytical equipment calibrations.
    7.1.10 For stack gas flow rate, diluent gas, and moisture 
monitoring systems, you must keep records of all certification, 
recertification, diagnostic, and on-going quality-assurance tests of 
these systems, as specified in 40 CFR 75.59(a).
    7.1.11 For each temperature measurement device (e.g., RTD or 
thermocouple) and pressure measurement device used to convert 
measured PM concentrations to standard conditions according to 
Equation C-1 or C-2 in section 6.2.1 of this appendix, you must keep 
records of all calibrations and other checks performed to ensure 
that accurate data are obtained.
    7.2 Reporting Requirements.
    7.2.1 General Reporting Provisions. You must comply with the 
following requirements for reporting PM emissions from each affected 
EGU (or group of EGUs monitored at a common stack) under this 
subpart:
    7.2.1.1 Notifications, in accordance with section 7.2.2 of this 
appendix;
    7.2.1.2 Monitoring plan reporting, in accordance with section 
7.2.3 of this appendix;
    7.2.1.3 Certification, recertification, and QA test submittals, 
in accordance with section 7.2.4 of this appendix; and
    7.2.1.4 Electronic quarterly emissions report submittals, in 
accordance with section 7.2.5 of this appendix.
    7.2.2 Notifications. You must provide notifications for each 
affected unit (or group of units monitored at a common stack) under 
this subpart in accordance with Sec.  63.10030.
    7.2.3 Monitoring Plan Reporting. For each affected unit (or 
group of units monitored at a common stack) under this subpart using 
PM CEMS to measure PM emissions, you must make electronic and hard 
copy monitoring plan submittals as follows:
    7.2.3.1 For an EGU that begins reporting hourly PM 
concentrations on January 1, 2024 with a previously-certified PM 
CEMS, submit the monitoring plan information in section 7.1.1.2 of 
this appendix prior to or concurrent with the first required 
quarterly emissions report. For a new EGU, or for an EGU switching 
to continuous monitoring of PM emissions after having implemented 
another allowable compliance option under this subpart, submit the 
information in section 7.1.1.2 of this appendix at least 21 days 
prior to the start of initial certification testing of the PM CEMS. 
Also submit the monitoring plan information in 40 CFR 75.53(g) 
pertaining to any required flow rate, diluent gas, and moisture 
monitoring systems within the applicable time frame specified in 
this section, if the required records are not already in place.
    7.2.3.2 Whenever an update of the monitoring plan is required, 
as provided in section 7.1.1.1 of this appendix, you must submit the 
updated information either prior to or concurrent with the relevant 
quarterly electronic emissions report.
    7.2.3.3 All electronic monitoring plan submittals and updates 
shall be made to the Administrator using the ECMPS Client Tool. Hard 
copy portions of the monitoring plan shall be submitted to the 
appropriate delegated authority.
    7.2.4 Certification, Recertification, and Quality-Assurance Test 
Reporting. Except for daily QA tests of the required monitoring 
systems (i.e., calibration error or drift tests, sample volume 
checks, system optics checks, and flow monitor interference checks), 
you must submit the results of all required certification, 
recertification, and quality-assurance tests described in sections 
7.1.9.1

[[Page 20372]]

through 7.1.9.6 and 7.1.10 of this appendix electronically (except 
for test results previously submitted, e.g., under the Acid Rain 
Program), using the ECMPS Client Tool. Submit the results of the QA 
test (i.e., RCA or RRA) or, if applicable, a new PM CEMS correlation 
test, either prior to or concurrent with the relevant quarterly 
electronic emissions report. If this is not possible, you have up to 
60 days after the test completion date to submit the test results; 
in this case, you may claim provisional status for the emissions 
data affected by the QA test or correlation, starting from the date 
and hour in which the test was completed and continuing until the 
date and hour in which the test results are submitted. For an RRA or 
RCA, if the applicable audit specifications are met, the status of 
the emissions data in the relevant time period changes from 
provisional to quality-assured, and no further action is required. 
For a successful correlation test, apply the correlation equation 
retrospectively to the raw data to change the provisional status of 
the data to quality-assured, and resubmit the affected emissions 
report(s). However, if the applicable performance specifications are 
not met, the provisional data must be invalidated, and resubmission 
of the affected quarterly emission report(s) is required. For a 
failed RRA or RCA, you must take corrective actions and proceed 
according to the applicable requirements found in sections 10.5 
through 10.7 of Procedure 2 in appendix F to part 60 of this chapter 
until a successful QA test report is submitted. If a correlation 
test is unsuccessful, you may not report quality-assured data from 
the PM CEMS until the results of a subsequent correlation test show 
that the specifications in section 13.0 of PS-11 in appendix B to 
part 60 of this chapter are met.
    7.2.5 Quarterly Reports.
    7.2.5.1 For each affected EGU (or group of EGUs monitored at a 
common stack), the owner or operator must use the ECMPS Client Tool 
to submit electronic quarterly emissions reports to the 
Administrator, in an XML format specified by the Administrator, 
starting with a report for the later of:
    7.2.5.1.1 The first calendar quarter of 2024; or
    7.2.5.1.2 The calendar quarter in which the initial PM CEMS 
correlation test is completed.
    7.2.5.2 You must submit the electronic reports within 30 days 
following the end of each calendar quarter, except for EGUs that 
have been placed in long-term cold storage (as defined in 40 CFR 
72.2).
    7.2.5.3 Each of your electronic quarterly reports shall include 
the following information:
    7.2.5.3.1 The date of report generation;
    7.2.5.3.2 Facility identification information;
    7.2.5.3.3 The information in sections 7.1.2 through 7.1.7 of 
this appendix that is applicable to your PM emission measurement 
methodology; and
    7.2.5.3.4 The results of all daily QA assessments, i.e., 
calibration drift checks and (if applicable) sample volume checks of 
the PM CEMS, calibration error tests of the other continuous 
monitoring systems that are used to convert PM concentration to 
units of the standard, and (if applicable) flow monitor interference 
checks.
    7.2.5.4 Compliance Certification. Based on a reasonable inquiry 
of those persons with primary responsibility for ensuring that all 
PM emissions from the affected unit(s) under this subpart have been 
correctly and fully monitored, the owner or operator must submit a 
compliance certification in support of each electronic quarterly 
emissions monitoring report. The compliance certification shall 
include a statement by a responsible official with that official's 
name, title, and signature, certifying that, to the best of his or 
her knowledge, the report is true, accurate, and complete.

0
18. Add appendix D to subpart UUUUU to read as follows:

Appendix D to Subpart UUUUU of Part 63--PM CPMS Monitoring Provisions

1. General Provisions

    1.1 Applicability. These monitoring provisions apply to the 
continuous monitoring of the output from a particulate matter 
continuous parametric monitoring system (PM CPMS), for the purpose 
of assessing continuous compliance with an applicable emissions 
limit in Table 1 or 2 to this subpart.
    1.2 Summary of the Method. The output from an instrument capable 
of continuously measuring PM concentration is continuously recorded, 
either in milliamps, PM concentration, or other units of measure. An 
operating limit for the PM CPMS is established initially, based on 
data recorded by the monitoring system during a performance stack 
test. The performance test is repeated annually and the operating 
limit is reassessed. In-between successive performance tests, the 
output from the PM CPMS serves as an indicator of continuous 
compliance with the applicable emissions limit.

2. Continuous Monitoring of the PM CPMS Output

    2.1 System Design and Performance Criteria. The PM CPMS must 
meet the design and performance criteria specified in Sec. Sec.  
63.10010(h)(1)(i) through (iii) and 63.10023(b)(2)(iii) and (iv). In 
addition, an automated data acquisition and handling system (DAHS) 
is required to record the output from the PM CPMS and to generate 
the quarterly electronic data reports required under section 3.2.4 
of this appendix.
    2.2 Installation Requirements. Install the PM CPMS at an 
appropriate location in the stack or duct, in accordance with Sec.  
63.10010(a).
    2.3 Determination of Operating Limits.
    2.3.1 In accordance with Sec. Sec.  63.10007(a)(3), 63.10011(b), 
and 63.10023(a) and Table 6 to this subpart, you must determine an 
initial site-specific operating limit for your PM CPMS, using data 
recorded by the monitoring system during a performance stack test 
that demonstrates compliance with one of the following emissions 
limits in Table 1 or 2 to this subpart: Filterable PM; total non-Hg 
HAP metals; total HAP metals including Hg (liquid oil-fired units, 
only); individual non-Hg HAP metals; or individual HAP metals 
including Hg (liquid oil-fired units, only).
    2.3.2 In accordance with Sec.  63.10005(d)(2)(i), you must 
perform the initial stack test no later than the applicable date in 
Sec.  63.9984(f), and according to Sec. Sec.  63.10005(d)(2)(iii) 
and 63.10006(a), the performance test must be repeated annually to 
document compliance with the emissions limit and to reassess the 
operating limit.
    2.3.3 Calculate the operating limits according to Sec.  
63.10023(b)(1) for existing units, and Sec.  63.10023(b)(2) for new 
units.
    2.4 Data Reduction and Compliance Assessment.
    2.4.1 Reduce the output from the PM CPMS to hourly averages, in 
accordance with Sec.  63.8(g)(2) and (5).
    2.4.2 To determine continuous compliance with the operating 
limit, you must calculate 30-boiler operating day rolling average 
values of the output from the PM CPMS, in accordance with Sec. Sec.  
63.10010(h)(3) through (6) and 63.10021(c) and Table 7 to this 
subpart.
    2.4.3 In accordance with Sec. Sec.  63.10005(d)(2)(ii) and 
63.10022(a)(2) and Table 4 to this subpart, the 30-boiler operating 
day rolling average PM CPMS output must be maintained at or below 
the operating limit. However, if exceedances of the operating limit 
should occur, you must follow the applicable procedures in Sec.  
63.10021(c)(1) and (2).

3. Recordkeeping and Reporting

    3.1 Recordkeeping Provisions. You must keep the applicable 
records required under Sec.  63.10032(b) and (c) for your PM CPMS. 
In addition, you must maintain a file of all measurements, data, 
reports, and other information required by this appendix in a form 
suitable for inspection, for 5 years from the date of each record, 
in accordance with Sec.  63.10033.
    3.1.1 Monitoring Plan Records.
    3.1.1.1 You must develop and maintain a site-specific monitoring 
plan for your PM CPMS, in accordance with Sec.  63.10000(d).
    3.1.1.2 In addition to the site-specific monitoring plan 
required under Sec.  63.10000(d), you must use the ECMPS Client Tool 
to prepare and maintain an electronic monitoring plan for your PM 
CPMS.
    3.1.1.2.1 Contents of the Electronic Monitoring Plan. The 
electronic monitoring plan records must include the unit or stack ID 
number(s), monitoring location(s), the monitoring methodology used 
(i.e., PM CPMS), the current operating limit of the PM CPMS 
(including the units of measure), unique system and component ID 
numbers, the make, model, and serial number of the PM CPMS, the 
analytical principle of the monitoring system, and monitor span and 
range information.
    3.1.1.2.2 Electronic Monitoring Plan Updates. If you replace or 
make a change to a PM CPMS that is used to provide data under this 
subpart (including a change in the automated data acquisition and 
handling system) and the replacement or change affects information 
reported in the electronic monitoring plan (e.g., changes to the 
make, model and serial number when a PM CPMS

[[Page 20373]]

is replaced), you must update the monitoring plan.
    3.1.2 Operating Parameter Records. You must record the following 
information for each operating hour of each affected unit and for 
each group of units utilizing a common stack. For non-operating 
hours, record only the items in sections 3.1.2.1 and 3.1.2.2 of this 
appendix.
    3.1.2.1 The date and hour;
    3.1.2.2 The unit or stack operating time (rounded up to the 
nearest fraction of an hour (in equal increments that can range from 
one hundredth to one quarter of an hour, at the option of the owner 
or operator); and
    3.1.2.3 If applicable, a flag to indicate that the hour is an 
exempt startup or shutdown hour.
    3.1.3 PM CPMS Output Records. For each affected unit or common 
stack using a PM CPMS, you must record the following information for 
each unit or stack operating hour:
    3.1.3.1 The date and hour;
    3.1.3.2 Monitoring system and component identification codes for 
the PM CPMS, as provided in the electronic monitoring plan, for each 
operating hour in which the monitoring system is not out-of-control 
and a valid value of the output parameter is obtained;
    3.1.3.3 The hourly average output from the PM CPMS, for each 
operating hour in which the monitoring system is not out-of-control 
and a valid value of the output parameter is obtained, either in 
milliamps, PM concentration, or other units of measure, as 
applicable;
    3.1.3.4 A special code for each operating hour in which the PM 
CPMS is out-of-control and a valid value of the output parameter is 
not obtained; and
    3.1.3.5 Percent monitor data availability (PMA) for the PM CPMS, 
calculated in the manner established for SO2, 
CO2, O2 or moisture monitoring systems 
according to Sec.  75.32 of this chapter.
    3.1.4 Records of PM CPMS Audits and Out-of-Control Periods. In 
accordance with Sec.  63.10010(h)(7), you must record, and make 
available upon request, the results of PM CPMS performance audits, 
as well as the dates of PM CPMS out-of-control periods and the 
corrective actions taken to return the system to normal operation.
    3.2 Reporting Requirements.
    3.2.1 General Reporting Provisions. You must comply with the 
following requirements for reporting PM CPMS data from each affected 
EGU (or group of EGUs monitored at a common stack) under this 
subpart:
    3.2.1.1 Notifications, in accordance with section 3.2.2 of this 
appendix;
    3.2.1.2 Monitoring plan reporting, in accordance with section 
3.2.3 of this appendix;
    3.2.1.3 Report submittals, in accordance with sections 3.2.4 and 
3.2.5 of this appendix.
    3.2.2 Notifications. You must provide notifications for the 
affected unit (or group of units monitored at a common stack) in 
accordance with Sec.  63.10030.
    3.2.3 Monitoring Plan Reporting. For each affected unit (or 
group of units monitored at a common stack) under this subpart using 
a PM CPMS you must make monitoring plan submittals as follows:
    3.2.3.1 For units using the PM CPMS compliance option prior to 
January 1, 2024, submit the electronic monitoring plan information 
in section 3.1.1.2.1 of this appendix prior to or concurrent with 
the first required electronic quarterly report. For units switching 
to the PM CPMS methodology on or after January 1, 2024, submit the 
electronic monitoring plan no later than 21 days prior to the date 
on which the PM test is performed to establish the initial operating 
limit.
    3.2.3.2 Whenever an update of the electronic monitoring plan is 
required, as provided in section 3.1.1.2.2 of this appendix, the 
updated information must be submitted either prior to or concurrent 
with the relevant quarterly electronic emissions report.
    3.2.3.3 All electronic monitoring plan submittals and updates 
shall be made to the Administrator using the ECMPS Client Tool.
    3.2.3.4 In accordance with Sec.  63.10000(d), you must submit 
the site-specific monitoring plan described in section 3.1.1.1 of 
this appendix to the Administrator, if requested.
    3.2.4 Electronic Quarterly Reports.
    3.2.4.1 For each affected EGU (or group of EGUs monitored at a 
common stack) that is subject to the provisions of this appendix, 
reporting of hourly responses from the PM CPMS will begin either 
with the first operating hour in the third quarter of 2023 or the 
first operating hour after completion of the initial stack test that 
establishes the operating limit, whichever is later. The owner or 
operator must then use the ECMPS Client Tool to submit electronic 
quarterly reports to the Administrator, in an XML format specified 
by the Administrator, starting with a report for the later of:
    3.2.4.1.1 The first calendar quarter of 2024; or
    3.2.4.1.2 The calendar quarter in which the initial operating 
limit for the PM CPMS is established.
    3.2.4.2 The electronic quarterly reports must be submitted 
within 30 days following the end of each calendar quarter, except 
for units that have been placed in long-term cold storage (as 
defined in Sec.  72.2 of this chapter).
    3.2.4.3 Each electronic quarterly report shall include the 
following information:
    3.2.4.3.1 The date of report generation;
    3.2.4.3.2 Facility identification information; and
    3.2.4.3.3 The information in sections 3.1.2 and 3.1.3 of this 
appendix.
    3.2.4.4 Compliance Certification. Based on a reasonable inquiry 
of those persons with primary responsibility for ensuring that the 
output from the PM CPMS has been correctly and fully monitored, the 
owner or operator shall submit a compliance certification in support 
of each electronic quarterly report. The compliance certification 
shall include a statement by a responsible official with that 
official's name, title, and signature, certifying that, to the best 
of his or her knowledge, the report is true, accurate, and complete.
    3.2.5 Performance Stack Test Results. You must use the ECMPS 
Client Tool to report the results of all performance stack tests 
conducted to document compliance with the applicable emissions limit 
in Table 1 or 2 to this subpart, as follows:
    3.2.5.1 Report a summary of each test electronically, in XML 
format, in the relevant quarterly compliance report under Sec.  
63.10031(g); and
    3.2.5.2 Provide a complete stack test report as a PDF file, in 
accordance with Sec.  63.10031(f) or (h), as applicable.

0
19. Add appendix E to subpart UUUUU to read as follows:

Appendix E to Subpart UUUUU of Part 63--Data Elements

    1.0 You must record the electronic data elements in this 
appendix that apply to your compliance strategy under this subpart. 
The applicable data elements in sections 2 through 13 of this 
appendix must be reported in the quarterly compliance reports 
required under Sec.  63.10031(g), in an XML format prescribed by the 
Administrator, starting with a report that covers the first quarter 
of 2024. For stack tests used to demonstrate compliance, RATAs, PM 
CEMS correlations, RRAs and RCAs that are completed on and after 
January 1, 2024, the applicable data elements in sections 17 through 
30 of this appendix must be reported in an XML format prescribed by 
the Administrator, and the information in section 31 of this 
appendix must be reported in as one or more PDF files.
    2.0 MATS Compliance Report Root Data Elements. You must record 
the following data elements and include them in each quarterly 
compliance report:
    2.1 ORIS Code;
    2.2 Facility Name;
    2.3 Facility Registry Identifier;
    2.4 Title 40 Part;
    2.5 Applicable Subpart;
    2.6 Calendar Year;
    2.7 Calendar Quarter; and
    2.8 Submission Comment (Optional).
    3.0 Performance Stack Test Summary. If you elect to demonstrate 
compliance using periodic performance stack testing (including 30-
boiler operating day Hg LEE tests), record the following data 
elements for each test:
    3.1 Parameter;
    3.2 Test Location ID;
    3.3 Test Number;
    3.4 Test Begin Date, Hour, and Minute;
    3.5 Test End Date, Hour, and Minute;
    3.6 Timing of Test (either performed on-schedule according to 
Sec.  63.10006(f), or was late);
    3.7 Averaging Plan Indicator;
    3.8 Averaging Group ID (if applicable);
    3.9 EPA Test Method Code;
    3.10 Emission Limit, Including Units of Measure;
    3.11 Average Pollutant Emission Rate;
    3.12 LEE Indicator;
    3.13 LEE Basis (if applicable); and
    3.14 Submission Comment (Optional).
    4.0 Operating limit Data (PM CPMS, only):
    4.1 Parameter Type;
    4.2 Operating Limit; and
    4.3 Units of Measure.
    5.0 Performance Test Run Data. For each run of the performance 
stack test, record the following data elements:
    5.1 Run Number;

[[Page 20374]]

    5.2 Run Begin Date, Hour, and Minute;
    5.3 Run End Date, Hour, and Minute;
    5.4 Pollutant Concentration and units of measure;
    5.5 Emission Rate;
    5.6 EPA test Method 19 Equation (if applicable);
    5.7 Total Sampling Time; and
    5.8 Total Sample Volume.
    6.0 Conversion Parameters. For the parameters that are used to 
convert the pollutant concentration to units of the emission 
standard (including, as applicable, CO2 or O2 
concentration, stack gas flow rate, stack gas moisture content, F-
factors, and gross output), record:
    6.1 Parameter Type;
    6.2 Parameter Source; and
    6.3 Parameter Value, including Units of Measure.
    7.0 QA Parameters: For key parameters that are used to quality-
assure the reference method data (including, as applicable, filter 
temperature, % isokinetic, leak check results, % breakthrough, % 
spike recovery, and relative deviation), record:
    7.1 Parameter Type;
    7.2 Parameter Value; and
    7.3 Pass/Fail Status.
    8.0 Averaging Group Configuration. If a particular EGU or common 
stack is included in an averaging plan, record the following data 
elements:
    8.1 Parameter Being Averaged;
    8.2 Averaging Group ID; and
    8.3 Unit or Common Stack ID.
    9.0 Compliance Averages. If you elect to (or are required to) 
demonstrate compliance using continuous monitoring system(s) on a 
30-boiler operating day rolling average basis (or on a 30- or 90-
group boiler operating day rolling weighted average emission rate 
(WAER) basis, if your monitored EGU or common stack is in an 
averaging plan), you must record the following data elements for 
each average emission rate (or, for units in an averaging plan, for 
each weighted average emission rate (WAER)):
    9.1 Unit or Common Stack ID;
    9.2 Averaging Group ID (if applicable);
    9.3 Parameter Being Averaged;
    9.4 Date;
    9.5 Average Type;
    9.6 Units of Measure; and
    9.7 Average Value.
    9.8 Comment Field.
    10.0 Unit Information. You must record the following data 
elements for each EGU:
    10.1 Unit ID;
    10.2 Date of Last Tune-up; and
    10.3 Emergency Bypass Information. If your coal-fired EGU, solid 
oil-derived fuel-fired EGU, or IGCC is equipped with a main stack 
and a bypass stack (or bypass duct) configuration, and has qualified 
to use the LEE compliance option, you must report the following 
emergency bypass information annually, in the compliance report for 
the fourth calendar quarter of the year:
    10.3.1 The number of emergency bypass hours for the year, as a 
percentage of the EGU's annual operating hours;
    10.3.2 A description of each emergency bypass event during the 
year, including the cause and corrective actions taken;
    10.3.3 An explanation of how clean fuels were burned to the 
maximum extent possible during each emergency bypass event;
    10.3.4 An estimate of the emissions released during each 
emergency bypass event. You must also show whether LEE status has 
been retained or lost, based on the emissions estimate and the 
results of the previous LEE retest; and
    10.3.5 If there were no emergency bypass events during the year, 
a statement to that effect.
    11.0 Fuel Usage Information. Record the following monthly fuel 
usage information:
    11.1 Calendar Month;
    11.2 Each Type of Fuel Used During the Calendar Month in the 
Quarter;
    11.3 Quantity of Each Type of Fuel Combusted in Each Calendar 
Month in the Quarter, with Units of Measure;
    11.3 New Fuel Type Indicator (if applicable); and
    11.4 Date of Performance Test Using the New Fuel (if 
applicable).
    12.0 Malfunction Information (if applicable): If there was a 
malfunction of the process equipment or control equipment during the 
reporting period that caused (or may have caused) an exceedance of 
an emissions or operating limit, record:
    12.1 Event Begin Date and Hour (if known);
    12.2 Event End Date and Hour;
    12.3 Malfunction Description; and
    12.4 Corrective Action.
    13.0 Deviations. If there were any deviations during the 
reporting period, record:
    13.1 Unit, Common Stack, or Averaging Group ID;
    13.2 The nature of the deviation, as either:
    13.2.1 Emission limit exceeded;
    13.2.2 Operating limit exceeded;
    13.2.3 Work practice standard not met;
    13.2.4 Testing requirement not met;
    13.2.5 Monitoring requirement not met; or
    13.2.6 Other requirement not met.
    13.3 A description of the deviation, as follows:
    13.3.1 For a performance stack test or a 30- (or 90-) boiler 
operating day rolling average that exceeds an emissions or operating 
limit, record the parameter (e.g., HCl, Hg, PM), the limit that was 
exceeded, and either the date of the non-complying performance test 
or the beginning and ending dates of the non-complying rolling 
average;
    13.3.2 If an unmonitored bypass stack was used during the 
reporting period, record the total number of hours of bypass stack 
usage;
    13.3.3 For failure to collect required monitoring data during 
the reporting period, record the monitored parameter, the total 
source operating time (hours), and the total number of hours of 
monitor downtime for:
    13.3.3.1 Monitoring system malfunctions;
    13.3.3.2 Out-of-control periods;
    13.3.3.3 Non-monitoring equipment malfunctions;
    13.3.3.4 QA/QC activities (e.g., calibrations, performance 
audits)
    13.3.3.5 Routine maintenance
    13.3.3.6 Other known causes; and
    13.3.3.7 Unknown causes.
    13.3.4 If a performance stack test was due within the quarter 
but was not done, record the parameter (e.g., HCl, PM), the test 
deadline, and a statement that the test was not done as required;
    13.3.5 For a late performance stack test conducted during the 
quarter, record the parameter, the test deadline, and the number of 
days that elapsed between the test deadline and the test completion 
date.
    13.4 Record any corrective actions taken in response to the 
deviation.
    13.5 If there were no deviations during the quarter, record a 
statement to that effect.
    14.0 Reference Method Data Elements. For each of the following 
tests that is completed on and after January 1, 2024, you must 
record and report the applicable electronic data elements in 
sections 17 through 29 of this appendix, pertaining to the reference 
method(s) used for the test (see section 16 of this appendix).
    14.1 Each quarterly, annual, or triennial stack test used to 
demonstrate compliance (including 30- (or 90-) boiler operating day 
Hg LEE tests and PM tests used to set operating limits for PM CPMS);
    14.2 Each relative accuracy test audit (RATA) of your Hg, HCl, 
HF, or SO2 CEMS or each RATA of your Hg sorbent trap 
monitoring system; and
    14.3 Each correlation test, relative response audit (RRA) and 
each response correlation audit (RCA) of your PM CEMS.
    15.0 You must report the applicable data elements for each test 
described in section 14 of this appendix in an XML format prescribed 
by the Administrator.
    15.1 For each stack test completed during a particular calendar 
quarter and contained in the quarterly compliance report, you must 
submit along with the quarterly compliance report, the data elements 
in sections 17 and 18 of this appendix (which are common to all 
tests) and the applicable data elements in sections 19 through 31 of 
this appendix associated with the reference method(s) used.
    15.2 For each RATA, PM CEMS correlation, RRA, or RCA, when you 
use the ECMPS Client Tool to report the test results as required 
under appendix A, B, or C to this subpart or, for SO2 
RATAs under part 75 of this chapter, you must submit along with the 
test results, the data elements in sections 17 and 18 of this 
appendix and, for each test run, the data elements in sections 19 
through 30 of this appendix that are associated with the reference 
method(s) used.
    15.3 For each stack test, RATA, PM CEMS correlation, RRA, and 
RCA, you must also provide the information described in section 31 
of this appendix as a PDF file, either along with the quarterly 
compliance report (for stack tests) or together with the test 
results reported under appendix A, B, or C to this subpart or part 
75 of this chapter (for RATAs, RRAs, RCAs, or PM CEMS correlations).
    16.0 Applicable Reference Methods. One or more of the following 
EPA reference methods is needed for the tests described in sections 
14.1 through 14.3 of this appendix: Method 1, Method 2, Method 3A, 
Method 4, Method 5, Method 5D, Method 6C, Method 26, Method 26A, 
Method 29, and/or Method

[[Page 20375]]

30B in appendices A-1 through A-4 and A-8 of part 60 of this 
chapter.
    16.1 Application of EPA test Methods 1 and 2 in appendices A-1 
of part 60 of this chapter. If you use periodic stack testing to 
comply with an output-based emissions limit, you must determine the 
stack gas flow rate during each performance test run in which EPA 
test Method 5, 5D, 26, 26A, 29, or 30B in appendices A-3 and A-8 of 
part 60 of this chapter is used, in order to convert the measured 
pollutant concentration to units of the standard. For EPA test 
Methods 5, 5D, 26A and 29, which require isokinetic sampling, the 
delta-P readings made with the pitot tube and manometer at the 
Method 1 traverse points, taken together with measurements of stack 
gas temperature, pressure, diluent gas concentration (from a 
separate EPA test Method 3A or 3B test) and moisture, provide the 
necessary data for the EPA test Method 2 flow rate calculations. 
Note that even if you elect to comply with a heat input-based 
standard, when EPA test Method 5, 5D, 26A, or 29 is used, you must 
still use EPA test Method 2 to determine the average stack gas 
velocity (vs), which is needed for the percent isokinetic 
calculation. The EPA test Methods 26 and 30B do not require 
isokinetic sampling; therefore, when either of these methods is 
used, if the stack gas flow rate is needed to comply with the 
applicable output-based emissions limit, you must make a separate 
EPA test Method 2 determination during each test run.
    16.2 Application of EPA test Method 3A in appendix A-2 of part 
60 of this chapter. If you elect to perform periodic stack testing 
to comply with a heat input-based emissions limit, a separate 
measurement of the diluent gas (CO2 or O2) 
concentration is required for each test run in which EPA test Method 
5, 5D, 26, 26A, 29, or 30B in appendices A-3 and A-8 of part 60 of 
this chapter is used, in order to convert the measured pollutant 
concentration to units of the standard. The EPA test Method 3A is 
the preferred CO2 or O2 test method, although 
EPA test Method 3B may be used instead. Diluent gas measurements are 
also needed for stack gas molecular weight determinations when using 
EPA test Method 2 in appendix A-1 of part 60 of this chapter.
    16.3 Application of EPA test Method 4 in appendix A-3 of part 60 
of this chapter. For performance stack tests, depending on which 
equation is used to convert pollutant concentration to units of the 
standard, measurement of the stack gas moisture content, using EPA 
test Method 4, may also be required for each test run. The EPA test 
Method 4 moisture data are also needed for the EPA test Method 2 in 
appendix A-1 of part 60 of this chapter calculations (to determine 
the molecular weight of the gas) and for the RATA of an Hg CEMS that 
measures on a wet basis, when RM 30B is used. Other applications 
that require EPA test Method 4 moisture determinations include: 
RATAs of an SO2 monitor, when the reference method and 
CEMS data are measured on a different moisture basis (wet or dry); 
conversion of wet-basis pollutant concentrations to the units of a 
heat input-based emissions limit when certain equations in EPA test 
Method 19 in appendix A-7 of part 60 of this chapter are used (e.g., 
Eq. 19-3, 19-4, or 19-8); and stack gas molecular weight 
determinations. When EPA test Method 5, 5D, 26A, or 29 in appendices 
A-3 and A-8 of part 60 of this chapter is used for the performance 
test, the EPA test Method 4 moisture determination may be made by 
using the water collected in the impingers together with data from 
the dry gas meter; alternatively, a separate EPA test Method 4 
determination may be made. However, when EPA test Method 26 or 30B 
in appendix A-8 of part 60 of this chapter is used, EPA test Method 
4 must be performed separately.
    16.4 Applications of EPA test Methods 5 and 5D in appendix A-3 
of part 60 of this chapter. The EPA test Method 5 (or, if applicable 
5D) must be used for the following applications: to demonstrate 
compliance with a filterable PM emissions limit; for PM tests used 
to set operating limits for PM CPMS; and for the initial 
correlations, RRAs and RCAs of a PM CEMS.
    16.5 Applications of EPA test Method 6C in appendix A-4 of part 
60 of this chapter. If you elect to monitor SO2 emissions 
from your coal-fired EGU as a surrogate for HCl, the SO2 
CEMS must be installed, certified, operated, and maintained 
according to 40 CFR part 75. Part 75 allows the use of EPA test 
Methods 6, 6A, 6B, and 6C in appendix A-4 of part 60 of this chapter 
for the required RATAs of the SO2 monitor. However, in 
practice, only instrumental EPA test Method 6C is used.
    16.6 Applications of EPA test Methods 26 and 26A in appendix A-8 
of pat 60 of this chapter. The EPA test Method 26A may be used for 
quarterly HCl or HF stack testing, or for the RATA of an HCl or HF 
CEMS. The EPA test Method 26 may be used for quarterly HCl or HF 
stack testing; however, for the RATAs of an HCl monitor that is 
following Performance Specification 18 and Procedure 6 in appendices 
B and F to part 60 of this chapter, EPA test Method 26 may only be 
used if approved upon request.
    16.7 Applications of EPA test Method 29 in appendix A-8 of part 
60 of this chapter. The EPA test Method 29 may be used for periodic 
performance stack tests to determine compliance with individual or 
total HAP metals emissions limits. For coal-fired EGUs, the total 
HAP emissions limits exclude Hg.
    16.8 Applications of EPA test Method 30B in appendix A-8 of part 
60 of this chapter. The EPA test Method 30B is used for 30- (or 90-) 
boiler operating day Hg LEE tests and RATAs of Hg CEMS and sorbent 
trap monitoring systems, and it may be used for quarterly Hg stack 
testing (oil-fired EGUs, only).
    17.0 Facility and Test Company Information. In accordance with 
Sec.  63.7(e)(3), a test is defined as three or more runs of one or 
more EPA Reference Method(s) conducted to measure the amount of a 
specific regulated pollutant, pollutants, or surrogates being 
emitted from a particular EGU (or group of EGUs that share a common 
stack), and to satisfy requirements of this subpart. On or after 
January 1, 2024, you must report the data elements in sections 17 
and 18, each time that you complete a required performance stack 
test, RATA, PM CEMS correlation, RRA, or RCA at the affected EGU(s), 
using EPA test Method 5, 5B, 5D, 6C, 26, 26A, 29, or 30B in 
appendices A-3 and A-8 of part 60 of this chapter. You must also 
report the applicable data elements in sections 19 through 25 of 
this appendix for each test. If any separate, corresponding EPA test 
Method 2, 3A, or 4 in appendices A-1 through A-3 of part 60 of this 
chapter test is conducted to in order to convert a pollutant 
concentration to the units of the applicable emission standard given 
in Table 1 or 2 to this subpart or to convert pollutant 
concentration from wet to dry basis (or vice-versa), you must also 
report the applicable data elements in sections 26 through 31 of 
this appendix.
    The applicable data elements in sections 17 through 31 of this 
appendix must be submitted separately, in XML format, along with the 
quarterly Compliance Report (for stack tests) or along with the 
electronic test results submitted to the ECMPS Client Tool (for CMS 
performance evaluations). The Electronic Reporting Tool (ERT) or an 
equivalent schema can be utilized to create this XML file. Note: 
Ideally, for all of the tests completed at a given facility in a 
particular calendar quarter, the applicable data elements in 
sections 17 through 31 of this appendix should be submitted together 
in one XML file. However, as shown in Table 8 to this subpart, the 
timelines for submitting stack test results and CMS performance 
evaluations are not identical. Therefore, for calendar quarters in 
which both types of tests are completed, it may not be possible to 
submit the applicable data elements for all of those tests in a 
single XML file; separate submittals may be necessary to meet the 
applicable reporting deadlines.
    17.1 Part;
    17.2 Subpart;
    17.3 ORIS Code;
    17.4 Facility Name;
    17.5 Facility Address;
    17.6 Facility City;
    17.7 Facility County;
    17.8 Facility State;
    17.9 Facility Zip Code;
    17.10 Facility Point of Contact;
    17.11 Facility Contact Phone Number;
    17.12 Facility Contact Email;
    17.13 EPA Facility Registration System (FRS) Number;
    17.14 Source Classification Code (SCC);
    17.15 State Facility ID;
    17.16 Project Number;
    17.17 Name of Test Company;
    17.18 Test Company Address;
    17.19 Test Company City;
    17.20 Test Company State;
    17.21 Test Company Zip Code;
    17.22 Test Company Point of Contact;
    17.23 Test Company Contact Phone Number;
    17.24 Test Company Contact Email; and
    17.25 Test Comment (Optional).
    18.0 Source Information Data Elements. You must report the 
following data elements, as applicable, for each source for which at 
least one test is included in the XML file:
    18.1 Source ID (Sampling Location);
    18.2 Stack (Duct) Diameter (Circular Stack) (in.);
    18.3 Equivalent Diameter (Rectangular Duct or Stack) (in.);

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    18.4 Area of Stack;
    18.5 Control Device Code; and
    18.6 Control Device Description.
    19.0 Run-Level and Lab Data Elements for EPA test Methods 5, 5B, 
5D, 26A, and 29 of Appendices A-3 and A-8 of Part 60 of this 
Chapter. You must report the appropriate Source ID (i.e., Data 
Element 18.1) and the following data elements, as applicable, for 
each run of each performance stack test, PM CEMS correlation test, 
RATA, RRA, or RCA conducted using isokinetic EPA test Method 5, 5B, 
5D, or 26A. If your EGU is oil-fired and you use EPA test Method 26A 
to conduct stack tests for both HCl and HF, you must report these 
data elements separately for each pollutant. When you use EPA test 
Method 29 to measure the individual HAP metals, total filterable 
HAPs metals and total HAP metals, report only the run-level data 
elements (sections 19.1, 19.3 through 19.30, and 19.38 through 19.41 
of this appendix), and the point-level and lab data elements in 
sections 20 and 21 of this appendix:
    19.1 Test Number;
    19.2 Pollutant Name;
    19.3 EPA Test Method;
    19.4 Run Number;
    19.5 Corresponding Reference Method(s), if applicable;
    19.6 Corresponding Reference Method(s) Run Number, if 
applicable;
    19.7 Number of Traverse Points;
    19.8 Run Begin Date;
    19.9 Run Start Time (Clock Time Start);
    19.10 Run End Date;
    19.11 Run End Time (Clock Time End);
    19.12 Barometric Pressure;
    19.13 Static Pressure;
    19.14 Cumulative Elapsed Sampling Time;
    19.15 Percent O2;
    19.16 Percent CO2;
    19.17 Pitot Tube ID;
    19.18 Pitot Tube Calibration Coefficient;
    19.19 Nozzle Calibration Diameter;
    19.20 F-Factor (Fd, Fw, or Fc);
    19.21 Calibration Coefficient of Dry Gas Meter (Y);
    19.22 Total Volume of Liquid Collected in Impingers and Silica 
Gel;
    19.23 Percent Moisture--Actual;
    19.24 Dry Molecular Weight of Stack Gas;
    19.25 Wet Molecular Weight of Stack Gas;
    19.26 Initial Reading of Dry Gas Meter Volume (dcf);
    19.27 Final Reading of Dry Gas Meter Volume (dcf);
    19.28 Stack Gas Velocity--fps;
    19.29 Stack Gas Flow Rate--dscfm;
    19.30 Type of Fuel;
    19.31 Pollutant Mass Collected (value);
    19.32 Pollutant Mass Unit of Measure;
    19.33 Detection Limit Flag;
    19.34 Pollutant Concentration;
    19.35 Pollutant Concentration Unit of Measure;
    19.36 Pollutant Emission Rate;
    19.37 Pollutant Emission Rate Units of Measure (in Units of the 
Standard);
    19.38 Compliance Limit Basis (Heat Input or Electrical Output);
    19.39 Heat Input or Electrical Output Unit of Measure;
    19.40 Process Parameter (value);
    19.41 Process Parameter Unit of Measure;
    19.42 Converted Concentration for PM CEMS only; and
    19.43 Converted Concentration Units (Units of Correlation for PM 
CEMS).
    20.0 Point-Level Data Elements for EPA test Methods 5, 5B, 5D, 
26A, & 29 in Appendices A-3 and A-8 of Part 60 of this Chapter. To 
link the point-level data with the run data in the xml schema, you 
must report the Source ID (i.e., Data Element 18.1), EPA Test Method 
(Data Element 19.3), Run Number (Data Element 19.4), and Run Begin 
Date (Data Element 19.8) with the following point-level data 
elements for each run of each performance stack test, PM CEMS 
correlation test, RATA, RRA, or RCA conducted using isokinetic EPA 
test Method 5, 5B, 5D, 26A, or 29. Note that these data elements are 
required for all EPA test Method 29 applications, whether the method 
is being used to measure the total or individual HAP metals 
concentrations:
    20.1 Traverse Point ID;
    20.2 Stack Temperature;
    20.3 Differential Pressure Reading ([Delta]P);
    20.4 Orifice Pressure Reading ([Delta]H);
    20.5 Dry Gas Meter Inlet Temperature;
    20.6 Dry Gas Meter Outlet Temperature; and
    20.7 Filter Temperature.
    21.0 Laboratory Results for EPA test Method 29 in Appendix A-8 
of Part 60 of this Chapter--Total or Individual Multiple HAP Metals. 
If you use EPA test Method 29 and elect to comply with the total or 
individual HAP metals standards, you must report run-level data 
elements 19.1 through 19.34 in section 19 of this appendix, and the 
point-level data elements in section 20 of this appendix. To link 
the laboratory data with the run data in the xml schema, you must 
report the Source ID (i.e., Data Element 18.1), EPA Test Method 
(Data Element 19.3), Run Number (Data Element 19.4), and Run Begin 
Date (Data Element 19.8) with the results of the laboratory 
analyses. Regardless of whether you elect to comply with the total 
HAP metals standard or the individual HAP metals standard, you must 
report the front half catch, the back half catch and the sum of the 
front and back half catches collected with EPA test Method 29 for 
each individual HAP metal and for the total HAP metals. The list of 
individual HAP metals is Antimony, Arsenic, Beryllium, Cadmium 
Chromium, Cobalt, Lead, Manganese, Nickel, Selenium and Mercury (if 
applicable). You must also calculate and report the pollutant 
emission rates(s) in relation to the standard(s) with which you have 
elected to comply and the units specified in Table 5 to this subpart 
as follows:
    21.1 Each Individual HAP metal total mass collected:
    21.1.1 Pollutant Name;
    21.1.2 Pollutant Mass Collected;
    21.1.3 Pollutant Mass Units of Measure; and
    21.1.4 Detection Limit Flag.
    21.2 Each Individual HAP metal Front Half:
    21.2.1 Pollutant Name;
    21.2.2 Pollutant Mass Collected;
    21.2.3 Pollutant Mass Units of Measure; and
    21.2.4 Detection Limit Flag.
    21.3 Each Individual HAP metal Back Half:
    21.3.1 Pollutant Name;
    21.3.2 Pollutant Mass Collected;
    21.3.3 Pollutant Mass Units of Measure; and
    21.3.4 Detection Limit Flag.
    21.4 Each Individual HAP metal concentration:
    21.4.1 Pollutant Name;
    21.4.2 Pollutant Concentration; and
    21.4.3 Pollutant Concentration Units of Measure.
    21.5 Each Individual HAP metal emission rate in units of the 
standard:
    21.5.1 Pollutant Name
    21.5.2 Pollutant Emission Rate and
    21.5.3 Pollutant Emission Rate Units of Measure.
    21.6 Each Individual HAP metal emission rate in units of lbs/
MMBTU or lbs/MW (per Table 5 to this subpart):
    21.6.1 Pollutant Name;
    21.6.2 Pollutant Emission Rate; and
    21.6.3 Pollutant Emission Rate Units of Measure.
    21.7 Total Filterable HAPs metals mass collected:
    21.7.1 Pollutant Name;
    21.7.2 Pollutant Mass Collected;
    21.7.3 Pollutant Mass Units of Measure; and
    21.7.4 Detection Limit Flag.
    21.8 Total Filterable HAPs metals concentration:
    21.8.1 Pollutant Name;
    21.8.2 Pollutant Concentration; and
    21.8.3 Pollutant Concentration Units of Measure.
    21.9 Total Filterable HAPs metals in units of lbs/MMBtu or lbs/
MW (per Table 5 to this subpart):
    21.9.1 Pollutant Name;
    21.9.2 Pollutant Emission Rate; and
    21.9.3 Pollutant Emission Rate Units of Measure.
    21.10 Total HAPs metals mass collected:
    21.10.1 Pollutant Name;
    21.10.2 Pollutant Mass Collected;
    21.10.3 Pollutant Mass Units of Measure; and
    21.10.4 Detection Limit Flag.
    21.11 Total HAPs metals concentration
    21.11.1 Pollutant Name;
    21.11.2 Pollutant Concentration; and
    21.11.3 Pollutant Concentration Units of Measure.
    21.12 Total HAPs metals Emission Rate in Units of the Standard:
    21.12.1 Pollutant Name;
    21.12.2 Pollutant Emission Rate; and
    21.12.3 Pollutant Emission Rate Units of Measure.
    21.13 Total HAPs metals Emission Rate in lbs/MMBtu or lbs/MW 
(per Table 5 to this subpart):
    21.13.1 Pollutant Name;
    21.13.2 Pollutant Emission Rate; and
    21.13.3 Pollutant Emission Rate Units of Measure.
    22.0 Run-Level and Lab Data Elements for EPA test Method 26 in 
Appendix A-8 to Part 60 of this Chapter. If you use EPA test Method 
26, you must report the Source ID (i.e., Data Element 18.1) and the 
following run-level data elements for each test run. If

[[Page 20377]]

your EGU is oil-fired and you use EPA test Method 26 to conduct 
stack tests for both HCl and HF, you must report these data elements 
separately for each pollutant:
    22.1 Test Number;
    22.2 Pollutant Name;
    22.3 EPA Test Method;
    22.4 Run Number;
    22.5 Corresponding Reference Method(s), if applicable;
    22.6 Corresponding Reference Method(s) Run Number, if 
applicable;
    22.7 Number of Traverse Points;
    22.8 Run Begin Date;
    22.9 Run Start Time (Clock Start Time);
    22.10 Run End Date;
    22.11 Run End Time (Clock End Time);
    22.12 Barometric Pressure;
    22.13 Cumulative Elapsed Sampling Time;
    22.14 Calibration Coefficient of Dry Gas Meter (Y);
    22.15 Initial Reading of Dry Gas Meter Volume (dcf);
    22.16 Final Reading of Dry Gas Meter Volume (dcf);
    22.17 Percent O2;
    22.18 Percent CO2;
    22.19 Type of Fuel;
    22.20 F-Factor (Fd, Fw, or Fc);
    22.21 Pollutant Mass Collected (value);
    22.22 Pollutant Mass Units of Measure;
    22.23 Detection Limit Flag;
    22.24 Pollutant Concentration;
    22.25 Pollutant Concentration Unit of Measure;
    22.26 Compliance Limit Basis (Heat Input or Electrical Output);
    22.27 Heat Input or Electrical Output Unit of Measure;
    22.28 Process Parameter (value);
    22.29 Process Parameter Unit of Measure;
    22.30 Pollutant Emission Rate; and
    22.31 Pollutant Emission Rate Units of Measure (in the Units of 
the Standard).
    23.0 Point-Level Data Elements for EPA test Method 26 in 
Appendix A-8 to Part 60 of this Chapter. To link the point-level 
data in this Section with the run-level data in the XML schema, you 
must report the Source ID (i.e., Data Element 18.1), EPA Test Method 
(Data Element 22.3), Run Number (Data Element 22.4), and Run Begin 
Date (Data Element 22.8) from section 22 of this appendix and the 
following point-level data elements for each run of each EPA test 
Method 26 test:
    23.1 Traverse Point ID;
    23.2 Filter Temperature; and
    23.3 Dry Gas Meter Temperature.
    24.0 Run-Level Data for EPA test Method 30B in Appendix A-8 to 
Part 60 of this Chapter. You must report Source ID (i.e., Data 
Element 18.1) and the following run-level data elements for each EPA 
test Method 30B test run:
    24.1 Test Number;
    24.2 Pollutant Name;
    24.3 EPA Test Method;
    24.4 Run Number;
    24.5 Corresponding Reference Method(s), if applicable;
    24.6 Corresponding Reference Method(s) Run Number, if 
applicable;
    24.7 Number of Traverse Points;
    24.8 Run Begin Date;
    24.9 Run Start Time (Clock Time Start);
    24.10 Run End Date;
    24.11 Run End Time (Clock Time End);
    24.12 Barometric Pressure;
    24.13 Percent O2;
    24.14 Percent CO2;
    24.15 Cumulative Elapsed Sampling Time;
    24.16 Calibration Coefficient of Dry Gas Meter Box A (Y);
    24.17 Initial Reading of Dry Gas Meter Volume (A);
    24.18 Final Reading of Dry Gas Meter Volume (A);
    24.19 Calibration Coefficient of Dry Gas Meter Box B (Y);
    24.20 Initial Reading of Dry Gas Meter Volume (B);
    24.21 Final Reading of Dry Gas Meter Volume (B);
    24.22 Gas Sample Volume Units of Measure;
    24.23 Post-Run Leak Rate (A);
    24.24 Post-Run Leak Check Vacuum (A);
    24.25 Post-Run Leak Rate (B);
    24.26 Post-Run Leak Check Vacuum (B);
    24.27 Sorbent Trap ID (A);
    24.28 Pollutant Mass Collected, Section 1 (A);
    24.29 Pollutant Mass Collected, Section 2 (A);
    24.30 Mass of Spike on Sorbent Trap A;
    24.31 Total Pollutant Mass Trap A;
    24.32 Sorbent Trap ID (B);
    24.33 Pollutant Mass Collected, Section 1 (B);
    24.34 Pollutant Mass Collected, Section 2 (B);
    24.35 Mass of Spike on Sorbent Trap B;
    24.36 Total Pollutant Mass Trap B;
    24.37 Pollutant Mass Units of Measure;
    24.38 Pollutant Average Concentration;
    24.39 Pollutant Concentration Units of Measure;
    24.40 Method Detection Limit (MDL);
    24.41 Percent Spike Recovery;
    24.42 Type of Fuel;
    24.43 F-Factor (Fd, Fw, or Fc);
    24.44 Compliance Limit Basis (Heat Input or Electrical Output);
    24.45 Heat Input or Electrical Output Unit of Measure;
    24.46 Process Parameter (value);
    24.47 Process Parameter Unit of Measure;
    24.48 Pollutant Emission Rate; and
    24.49 Pollutant Emission Rate Unit of Measure (in the Units of 
the Standard).
    25.0 Point-Level Data Elements for EPA test Method 30B in 
Appendix A-8 to Part 60 of this Chapter. You must report the Source 
ID (i.e., Data Element 18.1), EPA Test Method (Data Element 24.3), 
Run Number (Data Element 24.4), and Run Begin Date (Data Element 
24.8) and the following point-level data elements for each run of 
each EPA test Method 30B test:
    25.1 Traverse Point ID;
    25.2 Dry Gas Meter Temperature (A);
    25.3 Sample Flow Rate (A) (L/min);
    25.4 Dry Gas Meter Temperature (B); and
    25.5 Sample Flow Rate (B) (L/min).
    26.0 Pre-Run Data Elements for EPA test Methods 3A and 6C in 
Appendices A-2 and A-4 of Part 60 of this Chapter. You must report 
the Source ID (i.e., Data Element 18.1) and the following Pre-run 
data elements for each SO2 RATA using instrumental EPA 
test Method 6C, and for each instrumental EPA test Method 3A 
O2 or CO2 test that is performed to convert a 
pollutant concentration to the units of measure of the applicable 
emission unit of standard in Table 1 or 2 to this subpart:
    26.1 Test Number;
    26.2 EPA Test Method;
    26.3 Calibration Gas Cylinder Analyte;
    26.4 Cylinder Gas Units of Measure;
    26.5 Date of Calibration;
    26.6 Calibration Low-Level Gas Cylinder ID;
    26.7 Calibration Low-Level Gas Concentration;
    26.8 Calibration Low-Level Cylinder Expiration Date;
    26.9 Calibration Mid-Level Gas Cylinder ID;
    26.10 Calibration Mid-Level Gas Concentration;
    26.11 Calibration Mid-Level Cylinder Expiration Date;
    26.12 Calibration High-Level Gas Cylinder ID;
    26.13 Calibration High-Level Gas Concentration;
    26.14 Calibration High-Level Cylinder Expiration Date;
    26.15 Calibration Span;
    26.16 Low-Level Gas Response;
    26.17 Low-Level Calibration Error;
    26.18 Low-Level APS Flag;
    26.19 Mid-Level Gas Response;
    26.20 Mid-Level Calibration Error;
    26.21 Mid-Level APS Flag;
    26.22 High-Level Gas Response;
    26.23 High-Level Calibration Error; and
    26.24 High-Level APS Flag.
    27.0 Run-Level Data Elements for EPA test Methods 3A and 6C in 
Appendices A-2 and A-4 of Part 60 of this Chapter. You must report 
the Source ID (i.e., Data Element 18.1) and following run-level data 
elements for each run of each SO2 RATA using instrumental 
EPA test Method 6C, and for each run of each corresponding 
instrumental EPA test Method 3A test that is performed to convert a 
pollutant concentration to the applicable emission unit of standard 
in Table 1 or 2 to this subpart:
    27.1 Test Number;
    27.2 Pollutant or Analyte Name;
    27.3 EPA Test Method;
    27.4 Run Number;
    27.5 Corresponding Reference Method(s), if applicable;
    27.6 Corresponding Reference Method(s) Run Number(s), if 
applicable;
    27.7 Number of Traverse Points;
    27.8 Run Begin Date;
    27.9 Run Start Time (Clock Time Start);
    27.10 Run End Date;
    27.11 Run End Time (Clock Time End);
    27.12 Cumulative Elapsed Sampling Time;
    27.13 Upscale (mid or high) Gas Level;
    27.14 Pre-Run Low-Level Response;
    27.15 Pre-Run Low-Level System Bias;
    27.16 Pre-Run Low-Level Bias APS Flag;
    27.17 Pre-Run Upscale (mid or high) Response;
    27.18 Pre-Run Upscale (mid or high) System Bias;
    27.19 Pre-Run Upscale (mid or high) Bias APS Flag;

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    27.20 Post-Run Low-Level Response;
    27.21 Post-Run Low-Level System Bias;
    27.22 Post-Run Low-Level Bias APS Flag;
    27.23 Post-Run Low-Level Drift;
    27.24 Post-Run Low-Level Drift APS Flag;
    27.25 Post-Run Upscale (mid or high) Response;
    27.26 Post-Run Upscale (mid or high) System Bias;
    27.27 Post-Run Upscale (mid or high) System Bias APS Flag;
    27.28 Post-Run Upscale (mid or high) Drift;
    27.29 Post-Run Upscale (mid or high) Drift APS Flag;
    27.30 Unadjusted Raw Emissions Average Concentration;
    27.31 Calculated Average Concentration, Adjusted for Bias 
(Cgas);
    27.32 Concentration Units of Measure (Dry or wet);
    27.33 Type of Fuel;
    27.34 Process Parameter (value); and
    27.35 Process Parameter Units of Measure.
    28.0 Run-Level Data Elements for EPA test Method 2 in Appendix 
A-1 of Part 60 of this Chapter. When you make a separate 
determination of the stack gas flow rate using EPA test Method 2 
separately, corresponding to a pollutant reference method test, 
i.e., when data from the pollutant reference method cannot determine 
the stack gas flow rate, you must report the Source ID (i.e., 18.1) 
and following run-level data elements for each EPA test Method 2 
test run:
    28.1 Test Number;
    28.2 EPA Test Method;
    28.3 Run Number;
    28.4 Number of Traverse Points;
    28.5 Run Begin Date;
    28.6 Run Start Time (Clock Time Start);
    28.7 Run End Date;
    28.8 Run End Time (Clock Time End);
    28.9 Pitot Tube ID;
    28.10 Pitot Tube Calibration Coefficient;
    28.11 Barometric Pressure;
    28.12 Static Pressure;
    28.13 Percent O2;
    28.14 Percent CO2;
    28.15 Percent Moisture--actual;
    28.16 Dry Molecular Weight of Stack Gas;
    28.17 Wet Molecular Weight of Stack Gas;
    28.18 Stack Gas Velocity--fps; and
    28.19 Stack Gas Flow Rate--dscfm.
    29.0 Point-Level Data Elements for EPA test Method 2 in Appendix 
A-1 of Part 60 of this Chapter. For each run of each separate EPA 
test Method 2 test, you must report the Source ID (i.e., Data 
Element 18.1), EPA Test Method (Data Element 28.2), Run Number (Data 
Element 28.3), and Run Begin Date (Data Element 28.5) and the 
following point-level data elements:
    29.1 Traverse Point ID;
    29.2 Stack Temperature; and
    29.3 Differential Pressure Reading ([Delta]P).
    30.0 Run-Level Data Elements for EPA test Method 4 in Appendix 
A-3 of Part 60 of this Chapter. When you make a separate EPA test 
Method 4 determination of the stack gas moisture content 
corresponding to a pollutant reference method test, i.e., when data 
from the pollutant reference method cannot determine the moisture 
content, you must report the Source ID (i.e., Data Element 18.1) and 
the following run-level data elements for each EPA test Method 4 
test run:
    30.1 Test Number;
    30.2 EPA Test Method;
    30.3 Run Number;
    30.4 Number of Traverse Points;
    30.5 Run Begin Date;
    30.6 Run Start Time (Clock Time Start);
    30.7 Run End Date;
    30.8 Run End Time (Clock Time End);
    30.9 Barometric Pressure;
    30.10 Calibration Coefficient of Dry Gas Meter (Y);
    30.11 Volume of Water Collected in Impingers and Silica Gel;
    30.12 Percent Moisture-actual;
    30.13 Initial Reading of Dry Gas Meter Volume (dcf);
    30.14 Final Reading of Dry Gas Meter Volume (dcf); and
    30.15 Dry Gas Meter Temperature (Average).
    31.0 Other Information for Each Test or Test Series. You must 
provide each test included in the XML data file described in this 
appendix with supporting documentation, in a PDF file submitted 
concurrently with the XML file, such that all the data required to 
be reported by Sec.  63.7(g) are provided. That supporting data 
include but are not limited to diagrams showing the location of the 
test site and the sampling points, laboratory report(s) including 
analytical calibrations, calibrations of source sampling equipment, 
calibration gas cylinder certificates, raw instrumental data, field 
data sheets, QA data (e.g., field recovery spikes) and any required 
audit results and stack testers' credentials (if applicable). The 
applicable data elements in Sec.  63.10031(f)(6)(i) through (xii) of 
this section must be entered into ECMPS with each PDF submittal; the 
test number(s) (see Sec.  63.10031(f)(6)(xi)) must be included. The 
test number(s) must match the test number(s) in sections 19 through 
31 of this appendix (as applicable).

[FR Doc. 2020-07471 Filed 4-9-20; 8:45 am]
 BILLING CODE 6560-50-P